Consolidated Edison (ED) 10-K 18 Feb 21 2020 FY Annual report Financial data

Cover Page

Cover Page - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2020	Jan. 31, 2021	Jun. 30, 2020
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2020
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			$ 24
Entity Common Stock, Shares Outstanding		342,419,162
Amendment Flag	false
Document Fiscal Year Focus	2020
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	FY
Entity Central Index Key	0001047862
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 17, 2021, to be filed with the Commission pursuant to Regulation 14A, not later than 120 days after December 31, 2020, is incorporated in Part III of this report.
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
Entity Shell Company	false
Amendment Flag	false
Document Fiscal Year Focus	2020
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	FY
Entity Central Index Key	0000023632

Consolidated Income Statement

Consolidated Income Statement - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
OPERATING REVENUES
Total operating revenues	$ 12,246	$ 12,574	$ 12,337
OPERATING EXPENSES
Depreciation and amortization	1,920	1,684	1,438
Taxes, other than income taxes	2,575	2,406	2,266
TOTAL OPERATING EXPENSES	9,592	9,898	9,804
Gain on acquisition of Sempra Solar Holdings, LLC	0	0	131
OPERATING INCOME	2,654	2,676	2,664
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	(214)	96	119
Other income	23	45	17
Allowance for equity funds used during construction	17	14	12
Other deductions	(227)	(104)	(210)
TOTAL OTHER INCOME (DEDUCTIONS)	(401)	51	(62)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,253	2,727	2,602
INTEREST EXPENSE
Interest on long-term debt	915	888	780
Other interest	118	116	49
Allowance for borrowed funds used during construction	(14)	(13)	(10)
NET INTEREST EXPENSE	1,019	991	819
INCOME BEFORE INCOME TAX EXPENSE	1,234	1,736	1,783
INCOME TAX EXPENSE	90	296	401
NET INCOME	1,144	1,440	1,382
Income attributable to non-controlling interest	43	97	0
NET INCOME FOR COMMON STOCK	$ 1,101	$ 1,343	$ 1,382
Net income per common share — basic (in dollars per share)	$ 3.29	$ 4.09	$ 4.43
Net income per common share — diluted (in dollars per share)	$ 3.28	$ 4.08	$ 4.42
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (in shares)	334.8	328.5	311.7
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (in shares)	335.7	329.5	312.9
CECONY
OPERATING REVENUES
Total operating revenues	$ 10,647	$ 10,821	$ 10,680
OPERATING EXPENSES
Depreciation and amortization	1,598	1,373	1,276
Taxes, other than income taxes	2,456	2,295	2,156
TOTAL OPERATING EXPENSES	8,337	8,473	8,326
OPERATING INCOME	2,310	2,348	2,354
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	19	40	13
Allowance for equity funds used during construction	14	12	11
Other deductions	(204)	(87)	(167)
TOTAL OTHER INCOME (DEDUCTIONS)	(171)	(35)	(143)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,139	2,313	2,211
INTEREST EXPENSE
Interest on long-term debt	718	672	662
Other interest	33	67	36
Allowance for borrowed funds used during construction	(12)	(11)	(9)
NET INTEREST EXPENSE	739	728	689
INCOME BEFORE INCOME TAX EXPENSE	1,400	1,585	1,522
INCOME TAX EXPENSE	215	335	326
NET INCOME FOR COMMON STOCK	1,185	1,250	1,196
Electric
OPERATING REVENUES
Total operating revenues	8,730	8,694	8,612
Electric | CECONY
OPERATING REVENUES
Total operating revenues	8,103	8,062	7,971
Gas
OPERATING REVENUES
Total operating revenues	2,269	2,391	2,327
OPERATING EXPENSES
Operating costs	527	880	1,041
Gas | CECONY
OPERATING REVENUES
Total operating revenues	2,036	2,132	2,078
OPERATING EXPENSES
Operating costs	426	606	643
Steam
OPERATING REVENUES
Total operating revenues	508	627	631
Steam | CECONY
OPERATING REVENUES
Total operating revenues	508	627	631
Non-utility
OPERATING REVENUES
Total operating revenues	739	862	767
Purchased power
OPERATING EXPENSES
Operating costs	1,600	1,546	1,644
Purchased power | CECONY
OPERATING EXPENSES
Operating costs	1,432	1,357	1,433
Fuel
OPERATING EXPENSES
Operating costs	156	207	263
Fuel | CECONY
OPERATING EXPENSES
Operating costs	156	207	263
Other operations and maintenance
OPERATING EXPENSES
Operating costs	2,814	3,175	3,152
Other operations and maintenance | CECONY
OPERATING EXPENSES
Operating costs	$ 2,269	$ 2,635	$ 2,555

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Net income	$ 1,101	$ 1,343	$ 1,382
Net Income	1,144	1,440	1,382
INCOME ATTRIBUTABLE TO NON-CONTROLLING INTEREST	(43)	(97)	0
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	(6)	(5)	10
Other income, net of taxes	0	2	0
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
COMPREHENSIVE INCOME	1,095	1,340	1,392
CECONY
Net income	1,185	1,250	1,196
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	(1)	(3)	1
Other income, net of taxes	0	2	0
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	1
COMPREHENSIVE INCOME	$ 1,184	$ 1,249	$ 1,197

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
OPERATING ACTIVITIES
Net Income	$ 1,144	$ 1,440	$ 1,382
Net income	1,101	1,343	1,382
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,920	1,684	1,438
Impairment of assets	320	0	0
Deferred income taxes	85	308	408
Rate case amortization and accruals	(40)	(116)	(117)
Common equity component of allowance for funds used during construction	(17)	(14)	(12)
Net derivative (gains)/losses	57	27	8
(Gain) on Sale of Assets	0	(14)	0
Unbilled revenue and net unbilled revenue deferrals	(1)	(3)	18
(Gain) on existing project interests due to acquisition of Sempra Solar Holdings, LLC	0	0	(131)
Other non-cash items, net	127	(18)	115
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(543)	23	(140)
Materials and supplies, including fuel oil and gas in storage	(4)	6	(20)
Revenue decoupling mechanism receivable	(61)	(76)	0
Other receivables and other current assets	(134)	54	(62)
Taxes receivable	(6)	29	27
Prepayments	(11)	(73)	(7)
Accounts payable	170	10	(46)
Pensions and retiree benefits obligations, net	285	357	325
Pensions and retiree benefits contributions	(478)	(357)	(479)
Accrued taxes	74	10	(49)
Accrued interest	(4)	24	(35)
Superfund and environmental remediation costs, net	(22)	(9)	(19)
Distributions from equity investments	39	57	107
System benefit charge	(119)	20	92
Deferred charges, noncurrent assets and other regulatory assets	(653)	(492)	(393)
Deferred credits and other regulatory liabilities	10	278	436
Other current and noncurrent liabilities	60	(21)	(151)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,198	3,134	2,695
INVESTING ACTIVITIES
Utility construction expenditures	(3,326)	(3,238)	(3,251)
Cost of removal less salvage	(310)	(295)	(258)
Non-utility construction expenditures	(583)	(248)	(246)
Acquisition of Sempra Solar Holdings, LLC, net of cash acquired	0	0	(1,488)
Proceeds from sale of assets	0	192	5
Other investing activities	22	22	34
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,224)	(3,782)	(5,471)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	178	(874)	1,989
Issuance of long-term debt	2,925	3,017	3,030
Retirement of long-term debt	(518)	(1,195)	(1,938)
Debt issuance costs	(47)	(32)	(61)
Common stock dividends	(975)	(924)	(842)
Issuance of common shares - public offering	640	825	705
Issuance of common shares for stock plans	58	54	53
Distribution to noncontrolling interest	(16)	(12)	2
NET CASH FLOWS FROM FINANCING ACTIVITIES	2,245	859	2,938
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	219	211	162
BALANCE AT BEGINNING OF PERIOD	1,217	1,006	844
BALANCE AT END OF PERIOD	1,436	1,217	1,006
Cash paid/(received) during the period for:
Interest	920	876	805
Income taxes	38	(26)	0
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	478	336	369
Issuance of common shares for dividend reinvestment	48	47	47
Debt assumed with business acquisitions	0	0	568
Electric and Gas Transmission Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(3)	(205)	(248)
Renewable Electric Production Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(24)	(10)	(19)
CECONY
OPERATING ACTIVITIES
Net income	1,185	1,250	1,196
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,598	1,373	1,276
Deferred income taxes	168	128	354
Rate case amortization and accruals	(40)	(117)	(133)
Common equity component of allowance for funds used during construction	(14)	(12)	(11)
(Gain) on Sale of Assets	0	(14)	0
Unbilled revenue and net unbilled revenue deferrals	(47)	(3)	(4)
Other non-cash items, net	66	7	13
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(516)	3	(153)
Materials and supplies, including fuel oil and gas in storage	2	11	(17)
Revenue decoupling mechanism receivable	(53)	(76)	0
Other receivables and other current assets	(49)	54	(96)
Accounts receivables from affiliated companies	(61)	141	(150)
Prepayments	19	(61)	(9)
Accounts payable	145	(7)	(27)
Accounts payable to affiliated companies	9	(4)	7
Pensions and retiree benefits obligations, net	253	330	293
Pensions and retiree benefits contributions	(438)	(325)	(440)
Accrued taxes	61	11	(47)
Accrued taxes to affiliated companies	1	0	(72)
Accrued interest	13	1	(1)
Superfund and environmental remediation costs, net	(30)	(12)	(18)
System benefit charge	(112)	18	86
Deferred charges, noncurrent assets and other regulatory assets	(603)	(486)	(314)
Deferred credits and other regulatory liabilities	92	306	549
Other current and noncurrent liabilities	44	(14)	(78)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,693	2,502	2,204
INVESTING ACTIVITIES
Utility construction expenditures	(3,112)	(3,028)	(3,051)
Cost of removal less salvage	(304)	(288)	(255)
Proceeds from sale of assets	0	192	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,416)	(3,124)	(3,306)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	523	(55)	1,042
Issuance of long-term debt	2,200	1,300	2,740
Retirement of long-term debt	(350)	(475)	(1,836)
Debt issuance costs	(34)	(21)	(30)
Capital contribution by parent	500	900	120
Dividend to parent	(982)	(912)	(846)
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,857	737	1,190
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	134	115	88
BALANCE AT BEGINNING OF PERIOD	933	818	730
BALANCE AT END OF PERIOD	1,067	933	818
Cash paid/(received) during the period for:
Interest	693	676	662
Income taxes	102	73	195
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	417	285	299
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	51	80	100
Software Licenses | CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	48	76	95
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	28	33	0
Equipment | CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 28	$ 33	$ 0

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
CURRENT ASSETS
Cash and temporary cash investments	$ 1,272	$ 981
Accounts receivable - customers, less allowance for uncollectible accounts	1,701	1,236
Other receivables, less allowance for uncollectible accounts	278	184
Taxes receivable	26	20
Accrued unbilled revenue	599	599
Fuel oil, gas in storage, materials and supplies, at average cost	356	352
Prepayments	271	260
Regulatory assets	266	128
Restricted cash	164	236
Revenue decoupling mechanism receivable	137	76
Other current assets	231	200
TOTAL CURRENT ASSETS	5,301	4,272
INVESTMENTS	1,816	2,065
UTILITY PLANT, AT ORIGINAL COST
General	3,880	3,562
TOTAL	50,738	48,136
Less: Accumulated depreciation	11,188	10,322
Net	39,550	37,814
Construction work in progress	2,474	1,937
NET UTILITY PLANT	42,024	39,751
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	3,893	3,829
Construction work in progress	638	309
NET PLANT	46,555	43,889
OTHER NONCURRENT ASSETS
Goodwill	446	446
Intangible assets, less accumulated amortization of $228 and $126 in 2020 and 2019, respectively	1,460	1,557
Operating lease right-of-use-asset	837
Regulatory assets	6,195	4,859
Other deferred charges and noncurrent assets	285	134
TOTAL OTHER NONCURRENT ASSETS	9,223	7,853
TOTAL ASSETS	62,895	58,079
CURRENT LIABILITIES
Long-term debt due within one year	1,967	1,446
Term Loan	165	0
Notes payable	1,705	1,692
Accounts payable	1,475	1,164
Customer deposits	311	346
Accrued taxes	150	76
Accrued interest	149	153
Accrued wages	108	102
Fair value of derivative liabilities	238	123
Regulatory liabilities	36	102
System benefit charge	528	647
Operating lease liabilities	96	65
Other current liabilities	426	371
TOTAL CURRENT LIABILITIES	7,354	6,287
NONCURRENT LIABILITIES
Provision for injuries and damages	178	130
Pensions and retiree benefits	2,257	1,516
Superfund and other environmental costs	857	734
Asset retirement obligations	576	425
Fair value of derivative liabilities	240	105
Deferred income taxes and unamortized investment tax credits	6,475	6,227
Operating lease liabilities	764	809
Regulatory liabilities	4,513	4,827
Other deferred credits and noncurrent liabilities	234	279
TOTAL NONCURRENT LIABILITIES	16,094	15,052
LONG-TERM DEBT	20,382	18,527
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	18,847	18,022
Noncontrolling interest	218	191
TOTAL EQUITY (See Statement of Equity)	19,065	18,213
TOTAL LIABILITIES AND EQUITY	62,895	58,079
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	33,315	31,866
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	10,847	10,107
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,696	2,601
CECONY
CURRENT ASSETS
Cash and temporary cash investments	1,067	933
Accounts receivable - customers, less allowance for uncollectible accounts	1,595	1,153
Other receivables, less allowance for uncollectible accounts	134	120
Taxes receivable	8	0
Accrued unbilled revenue	523	477
Accounts receivable from affiliated companies	134	73
Fuel oil, gas in storage, materials and supplies, at average cost	291	293
Prepayments	159	178
Regulatory assets	244	113
Revenue decoupling mechanism receivable	129	76
Other current assets	123	127
TOTAL CURRENT ASSETS	4,407	3,543
INVESTMENTS	541	461
UTILITY PLANT, AT ORIGINAL COST
General	3,585	3,271
TOTAL	47,529	45,090
Less: Accumulated depreciation	10,297	9,490
Net	37,232	35,600
Construction work in progress	2,320	1,812
NET UTILITY PLANT	39,552	37,412
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	2	2
NET PLANT	39,554	37,414
OTHER NONCURRENT ASSETS
Goodwill	245	245
Operating lease right-of-use-asset	578	601
Regulatory assets	5,745	4,487
Other deferred charges and noncurrent assets	142	51
TOTAL OTHER NONCURRENT ASSETS	6,465	5,139
TOTAL ASSETS	50,967	46,557
CURRENT LIABILITIES
Long-term debt due within one year	640	350
Notes payable	1,660	1,137
Accounts payable	1,232	956
Customer deposits	296	334
Accounts payable to affiliated companies	22	13
Accrued taxes	132	71
Accrued taxes to affiliated companies	1	0
Accrued interest	126	113
Accrued wages	97	92
Fair value of derivative liabilities	163	81
Regulatory liabilities	11	63
System benefit charge	475	587
Operating lease liabilities	73	54
Other current liabilities	319	280
TOTAL CURRENT LIABILITIES	5,247	4,131
NONCURRENT LIABILITIES
Provision for injuries and damages	172	125
Pensions and retiree benefits	1,943	1,241
Superfund and other environmental costs	780	654
Asset retirement obligations	508	362
Fair value of derivative liabilities	105	65
Deferred income taxes and unamortized investment tax credits	6,411	6,000
Operating lease liabilities	512	551
Regulatory liabilities	4,094	4,427
Other deferred credits and noncurrent liabilities	197	240
TOTAL NONCURRENT LIABILITIES	14,722	13,665
LONG-TERM DEBT	16,149	14,614
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	14,849	14,147
TOTAL LIABILITIES AND EQUITY	50,967	46,557
CECONY | Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	31,327	29,989
CECONY | Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	9,921	9,229
CECONY | Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,696	$ 2,601

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Accounts receivable - customers, allowance for uncollectible accounts	$ 148	$ 70
Other receivables, allowance for uncollectible accounts	7	4
Non-utility property, accumulated depreciation	522	391
Intangible assets, accumulated amortization	228	126
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	138	65
Other receivables, allowance for uncollectible accounts	4	3
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	CECONY	CECONYCommon Stock	CECONYAdditional Paid-In Capital	CECONYRetained Earnings	CECONYRepurchased Con Edison Stock	CECONYCapital Stock Expense	CECONYAccumulated Other Comprehensive Income/(Loss)
BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2017		310,000,000								235,000,000
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2017	$ 15,425	$ 34	$ 6,298	$ 10,235	$ (1,038)	$ (85)	$ (26)	$ 7
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2017									$ 12,439	$ 589	$ 4,649	$ 8,231	$ (962)	$ (62)	$ (6)
TREASURY STOCK, BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2017					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,382								1,196			1,196
Net Income	1,382			1,382
Common stock dividends	(889)			(889)					(846)			(846)
Issuance of common shares - public offering (in shares)		11,000,000
Issuance of common shares - public offering	705		719			(14)
Issuance of common shares for stock plans	100		100
Capital contribution by parent									120		120
Other comprehensive income	10						10		1						1
Noncontrolling interest	106							106
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2018		321,000,000								235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2018	16,839	$ 34	7,117	10,728	$ (1,038)	(99)	(16)	113
BALANCE AS OF END OF PERIOD at Dec. 31, 2018									12,910	$ 589	4,769	8,581	(962)	(62)	(5)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2018					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,343								1,250			1,250
Net Income	1,440			1,343				97
Common stock dividends	(971)			(971)					(912)			(912)
Issuance of common shares - public offering (in shares)		12,000,000
Issuance of common shares - public offering	825	$ 1	835			(11)
Issuance of common shares for stock plans	102		102
Capital contribution by parent									900		900
Other comprehensive income	(3)						(3)		$ (1)						(1)
Noncontrolling interest	$ (19)							(19)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2019	332,629,597	333,000,000							235,488,094	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2019	$ 18,213	$ 35	8,054	11,100	$ (1,038)	(110)	(19)	191
BALANCE AS OF END OF PERIOD at Dec. 31, 2019	18,022								$ 14,147	$ 589	5,669	8,919	(962)	(62)	(6)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2019					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,101								1,185			1,185
Net Income	1,144			1,101				43
Common stock dividends	(1,023)			(1,023)					(982)			(982)
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
Capital contribution by parent									500		500
Other comprehensive income	(6)						(6)		$ (1)						(1)
Noncontrolling interest	$ (16)							(16)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020	342,297,534	342,000,000							235,488,094	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2020	$ 19,065	$ 36	$ 8,808	$ 11,178	$ (1,038)	$ (112)	$ (25)	$ 218
BALANCE AS OF END OF PERIOD at Dec. 31, 2020	$ 18,847								$ 14,849	$ 589	$ 6,169	$ 9,122	$ (962)	$ (62)	$ (7)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020					23,000,000

Consolidated Statement of Equ_2

Consolidated Statement of Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Statement of Stockholders' Equity [Abstract]
Common stock dividends per share (in dollars per share)	$ 3.06	$ 2.96	$ 2.86

Consolidated Statement of Capit

Consolidated Statement of Capitalization - USD ($) shares in Millions, $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Schedule of Capitalization, Equity [Line Items]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	342	333
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 18,872	$ 18,041
Pension plan liability adjustments, net of taxes	(23)	(17)
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	(2)	(2)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(25)	(19)
Equity	18,847	18,022
Noncontrolling interest	218	191
TOTAL EQUITY (See Statement of Equity)	$ 19,065	$ 18,213
CECONY
Schedule of Capitalization, Equity [Line Items]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	235	235
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 14,856	$ 14,153
Pension plan liability adjustments, net of taxes	(5)	0
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	(2)	(6)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(7)	(6)
Equity	14,849	14,147
TOTAL SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	$ 14,849	$ 14,147

Consolidated Statement of Cap_2

Consolidated Statement of Capitalization - Long-term Debt - USD ($) $ in Millions		Dec. 31, 2020	Dec. 31, 2019
Schedule of Capitalization, Long-term Debt [Line Items]
Other long-term debt		$ 971	$ 974
Unamortized debt expense		(168)	(141)
Unamortized debt discount		(47)	(37)
TOTAL		22,349	19,973
Less: Long-term debt due within one year			1,446
TOTAL LONG-TERM DEBT		20,382	18,527
TOTAL CAPITALIZATION		39,229	36,549
CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Unamortized debt expense		(130)	(115)
Unamortized debt discount		(46)	(36)
TOTAL		16,789	14,964
Less: Long-term debt due within one year			350
TOTAL LONG-TERM DEBT		16,149	14,614
TOTAL CAPITALIZATION		$ 30,998	28,761
Copper Mountain Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.04%
TOTAL PROJECT DEBT	[1]	$ 204	224
Coram
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT	[1]	$ 141	150
Coram | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.78%
Coram | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.52%
Copper Mountain Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.10%
TOTAL PROJECT DEBT	[1]	$ 264	289
CED Southwest
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.72%
TOTAL PROJECT DEBT	[1]	$ 437	456
Wind Holdings
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.41%
TOTAL PROJECT DEBT		$ 109	123
Copper Mountain Solar 1
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.41%
TOTAL PROJECT DEBT	[1]	$ 56	67
Mesquite Solar 1
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 180	193
Mesquite Solar 1 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.24%
Mesquite Solar 1 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.03%
Texas Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 54	56
Texas Solar 4 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
Texas Solar 4 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.95%
California Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.94%
TOTAL PROJECT DEBT		$ 93	98
California Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.07%
TOTAL PROJECT DEBT		$ 82	86
California Solar
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.78%
TOTAL PROJECT DEBT		$ 178	184
California Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.82%
TOTAL PROJECT DEBT		$ 284	297
Broken Bow II
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.82%
TOTAL PROJECT DEBT		$ 67	68
Texas Solar 5
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.53%
TOTAL PROJECT DEBT		$ 140	145
Texas Solar 7
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.21%
TOTAL PROJECT DEBT		$ 192	199
Upton County Solar
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL PROJECT DEBT		$ 87	90
Other project debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		10	12
Project Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		2,578	2,737
Debentures
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		18,565	15,990
Debentures | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 16,515	14,665
Debentures | Debenture Series 2010A, 4.45% Due 2020
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 0	350
Debentures | Debenture Series 2010A, 4.45% Due 2020 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 0	350
Debentures | Debenture Series 2016A, 2.00% Due 2021
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.00%
TOTAL		$ 500	500
Debentures | Debenture 2018C, 0.65 Percent, Due 2021
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.65%
TOTAL		$ 640	640
Debentures | Debenture 2020A, 0.65 Percent, Due 2023
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.65%
TOTAL	[2]	$ 650	0
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 2014B, 3.30 Percent, Due 2024 | CECONY
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 2016B, 2.90% Due 2026 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.90%
TOTAL		$ 250	250
Debentures | Debenture Series 1997F, 6.50% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.50%
TOTAL		$ 80	80
Debentures | Debenture Series 2017B, 3.125% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.125%
TOTAL		$ 350	350
Debentures | Debenture Series 2017B, 3.125% Due 2027 | CECONY
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 2018A, 3.80% Due 2028 | CECONY
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		4.00%
TOTAL		$ 500	500
Debentures | Debenture Series 2018D, 4.00% Due 2028 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
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	0
Debentures | Debenture 2020A, 3.35 Percent, Due 2030 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.35%
TOTAL		$ 600	0
Debentures | Debenture 2020A, 2.02 Percent, Due 2030
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.02%
TOTAL		$ 35	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 2003A, 5.875% Due 2033 | CECONY
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 2003C, 5.10% Due 2033 | CECONY
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 2004B, 5.70% Due 2034 | CECONY
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 2005A, 5.30% Due 2035 | CECONY
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 2005B, 5.25% Due 2035 | CECONY
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 2006A, 5.85% Due 2036 | CECONY
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 2006B, 6.20% Due 2036 | CECONY
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 2006E, 5.70% Due 2036 | CECONY
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 Series 2007A, 6.30% Due 2037 | CECONY
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 2008B, 6.75 Percent, Due 2038 | CECONY
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		6.00%
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 2009C, 5.50 Percent, Due 2039 | CECONY
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, 5.70 Percent, Due 2040 | CECONY
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 2012A, 4.20 Percent, Due 2042 | CECONY
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 2013A, 3.95 Percent, Due 2043 | CECONY
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 2014A, 4.45 Percent, Due 2044 | CECONY
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, 4.50 Percent, Due 2045 | CECONY
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 2016A, 3.85 Percent, Due 2046 | CECONY
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 2017A, 3.875% Due 2047 | CECONY
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 2018E, 4.65% Due 2048 | CECONY
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, 4.125 Percent, Due 2049 | CECONY
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	0
Debentures | Debenture 2020B, 3.95 Percent, Due 2050 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 1,000	0
Debentures | Debenture 2020B, 3.24 Percent, Due 2050
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.24%
TOTAL		$ 40	0
Debentures | Debenture Series 2014C, 4.625% Due 2054
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.625%
TOTAL		$ 750	750
Debentures | Debenture Series 2014C, 4.625% Due 2054 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.625%
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 2016C, 4.30% Due 2056 | CECONY
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		4.00%
TOTAL		$ 350	350
Debentures | Debenture Series 2017C, 4.00% Due 2057 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
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 Series 2018B, 4.50% Due 2058 | CECONY
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 2019B, 3.70 Percent, Due 2059 | CECONY
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		3.00%
TOTAL		$ 600	0
Debentures | Debenture 2020C, 3.00 Percent, Due 2060 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.00%
TOTAL		$ 600	0
Debentures | Debenture 2018C, 2.75 Percent, Due 2021 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.65%
TOTAL		$ 640	640
Tax-Exempt Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		450	450
Tax-Exempt Debt | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 450	450
Tax-Exempt Debt | Tax Exempt Debt Series 2010A Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.11%
TOTAL PROJECT DEBT	[2]	$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2010A Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.11%
TOTAL	[3]	$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 1.663% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.11%
TOTAL PROJECT DEBT	[2]	$ 99	99
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 1.663% Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.11%
TOTAL	[3]	$ 99	99
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 1.627% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.09%
TOTAL PROJECT DEBT	[2]	$ 126	126
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 1.627% Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.09%
TOTAL	[3]	$ 126	$ 126
[1]	December 31, 2020 effective rates shown, reflecting variable interest rates on the debt that are reset quarterly or semi-annually and the effect of applicable interest rate swaps, if any
[2]	Rates reset weekly or quarterly; December 31, 2020 rates shown.
[3]	Rates reset weekly or quarterly; December 31, 2020 rates shown.

General

General	12 Months Ended
	Dec. 31, 2020
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 and northern New Jersey and gas service in southeastern New York. Con Edison Clean Energy Businesses, Inc., which through its subsidiaries develops, owns and operates renewable and sustainable energy infrastructure projects and provide energy-related products and services to wholesale and retail customers. In December 2018, the Clean Energy Businesses acquired Sempra Solar Holdings, LLC. Con Edison Transmission, Inc. invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and holds investments in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See Note V.

Summary of Significant Accounti

Summary of Significant Accounting Policies and Other Matters	12 Months Ended
	Dec. 31, 2020
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 R), 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, 2020 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. Financial Instruments – Credit Losses Adoption of New Standard In January 2020, the Companies adopted Accounting Standards Update (ASU) 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendments replace the incurred loss impairment methodology which involved delayed recognition of credit losses. The amendments introduce an expected credit loss impairment model which requires immediate recognition of anticipated losses over the instrument’s life. A broader range of reasonable and supportable information must be considered in developing the credit loss estimates. The Companies' financial instruments subject to the amendments are included in the lines “Accounts receivable – customers” and “Other receivables.” Substantially all of these in-scope financial instruments are expected to be collected within one year of billing. The Companies adopted the amendments using the modified retrospective method for all financial instruments measured at amortized costs. Results for reporting periods beginning after January 1, 2020 are presented under Accounting Standards Codification (ASC) 326 while prior period amounts continue to be reported in accordance with previously applicable GAAP. No prior period adjustment or charge to retained earnings for cumulative impact was required as a result of the Companies’ adoption of the amendments. 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’ other receivables balance includes bills related to the sale of energy from renewable electric production projects. 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, 2020. 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. During the year of 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 $78 million and $73 million, respectively, for the year ended December 31, 2020. 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 year ended December 31, 2020: For the Year Ended December 31, 2020 Con Edison CECONY (Millions of Dollars) Accounts receivable - customers Other receivables Accounts receivable - customers Other receivables Allowance for credit losses Beginning Balance at January 1, 2020 $70 $4 $65 $3 Recoveries 8 — 6 — Write-offs (54) (2) (50) (1) Reserve adjustments 124 5 117 2 Ending Balance December 31, 2020 $148 $7 $138 $4 Revenues CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism, that covers all residential and most commercial customers, under which the company’s actual energy delivery revenues are compared with the authorized delivery revenues and the difference accrued, with interest, for refund to, or recovery from, customers, as applicable. See “Rate Plans” in Note B. The NYSPSC requires utilities to record gross receipts tax revenues and expenses on a gross income statement presentation basis (i.e., included in both revenue and expense). The recovery of these taxes is generally provided for in the revenue requirement within each of the respective NYSPSC-approved rate plans. Total excise taxes (inclusive of gross receipts taxes) recorded in operating revenues were as follows: For the Years Ended December 31, (Millions of Dollars) 2020 2019 2018 Con Edison $335 $323 $330 CECONY 323 312 318 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 S. 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, 5.1 percent and 5.4 percent for 2020, 2019 and 2018, respectively. The AFUDC rates for O&R were 5.3 percent, 5.3 percent and 2.2 percent for 2020, 2019 and 2018, 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 2020 and 3.2 percent for 2019 and 2018. The average depreciation rates for O&R were 3.2 percent for 2020, 3.0 percent for 2019 and 2.9 percent for 2018. The estimated lives for utility plant for CECONY range from 5 to 85 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, 2020 and 2019, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Electric Generation $572 $591 $572 $591 Transmission 3,786 3,634 3,496 3,380 Distribution 21,481 20,676 20,366 19,602 General 52 43 52 43 Gas (a) 9,206 8,617 8,522 7,961 Steam 1,854 1,813 1,854 1,813 General 2,507 2,365 2,286 2,143 Held for future use 92 75 84 67 Construction work in progress 2,474 1,937 2,320 1,812 Net Utility Plant $42,024 $39,751 $39,552 $37,412 (a) Primarily distribution. General utility plant of Con Edison and CECONY included $86 million and $81 million, respectively, at December 31, 2020, and $93 million and $88 million, respectively, at December 31, 2019, related to a May 2018 acquisition of software licenses. The estimated aggregate annual amortization expense for Con Edison and CECONY is $7 million. The accumulated amortization for Con Edison and CECONY was $17 million at December 31, 2020 and $10 million at December 31, 2019. Under the Utilities’ rate plans, the aggregate annual depreciation allowance for the period ended December 31, 2020 was $1,694 million, including $1,604 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 production 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. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on these assets 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 of Con Edison, net of accumulated depreciation, included $54 million ($51 million for CECONY) and $12 million ($11 million for CECONY), respectively at December 31, 2020, related to implementation costs incurred in cloud computing arrangements. The amounts recorded in 2019 were not material. Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. Depreciation expense related to these assets incurred during the year ended December 31, 2020 for Con Edison and CECONY was $7 million and $6 million, respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $10 million and $8 million, respectively at December 31, 2020 and was not material at December 31, 2019. 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, 2020 and 2019, intangible assets arising from power purchase agreements, including the PG&E PPAs (discussed below), were $1,457 million and $1,554 million, net of accumulated amortization of $220 million and $119 million, respectively, and are being amortized over the life of each agreement. Excluding power purchase agreements, Con Edison’s other intangible assets were $3 million, net of accumulated amortization of $8 million and $7 million, at December 31, 2020 and 2019, respectively. CECONY’s other intangible assets were immaterial at December 31, 2020 and 2019. Con Edison recorded amortization expense related to its intangible assets of $102 million in 2020, $99 million in 2019, and $14 million in 2018. Con Edison expects amortization expense to be $102 million per year over the next five years. Con Edison recorded $2 million of impairment charges in 2018. No impairment charges were recorded on Con Edison's long-lived assets or intangible assets with definite lives in 2020 or 2019. In January 2019, Pacific Gas and Electric Company (PG&E) filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code. The output of certain of the Clean Energy Businesses' renewable electric production projects is sold to PG&E under long-term power purchase agreements. As a result of the PG&E bankruptcy, distributions from the related projects to the Clean Energy Businesses were restricted and PG&E-related project debt was reclassified on Con Edison’s consolidated balance sheet from long-term debt to long-term debt due within one year. In July 2020, PG&E’s plan of reorganization became effective and the Clean Energy Businesses began receiving previously restricted distributions and all related project debt with a maturity longer than one year was reclassified to long-term debt. 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 and costs of its electric demand management programs 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 periodically evaluate its investments 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 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 involves 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 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. Con Edison evaluated its equity method investments and determined that there was an other-than-temporary decline in the value of its investment in Mountain Valley Pipeline LLC (MVP) and therefore recorded a partial impairment at December 31, 2020, as described below. Also, Con Edison is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC (Stagecoach), a joint venture that owns and operates an existing gas pipeline and storage business located in northeastern Pennsylvania and the southern tier of New York. As such strategic alternatives are evaluated, Con Edison may be required to determine whether an other-than-temporary decline in value has occurred for its Stagecoach investment. Partial Impairment of Investment in Mountain Valley Pipeline LLC (MVP) In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET Gas), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed gas transmission project (the Project) in West Virginia and Virginia. At December 31, 2020 and 2019, CET Gas' cash contributions to MVP were approximately $530 million, and the carrying value at December 31, 2020 prior to recording an impairment loss was $662 million, reflecting CET Gas' proportionate share of allowance for funds used during construction (AFUDC) income from the Project. During 2019, Con Edison determined that, as it was permitted to do under the MVP joint venture agreement, it would limit its cash contributions to the joint venture to approximately $530 million, which limit was reached in 2019, and that is expected to result in the further reduction of Con Edison’s ownership share in the joint venture. At December 31, 2020, CET Gas owned an 11.3 percent interest in MVP that is expected to be reduced to 8.8 percent based on the current project cost estimate and CET Gas’ previous capping of its cash contributions to the joint venture. 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 the first 77 miles of the Project in West Virginia, 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 amendment would lead to additional Project costs and would extend the anticipated in-service date of the Project to late 2021. The uncertainty related to obtaining the necessary permits in lieu of the Nationwide Permit 12, the resulting Project costs and the likelihood of the Project not reaching eventual completion have increased, constituting a triggering event which required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. Further, in January 2021, the FERC did not approve the requested amendment. In its discussion, a FERC commissioner indicated that the commission should have the plan for the entire Project’s water crossings rather than the first 77 miles and that all of the Federal permits be restored before allowing additional construction to resume. 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 certificate amendment for other water crossings that, in total, would cover the entire Project length. In addition, the second largest partner in the Project announced it had recorded a significant impairment of their investment in the Project at year-end 2020. In response to the 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. 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 T. 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. Con Edison believes that the likelihood of Project completion is in the upper end of a reasonably possible range. The likelihood that the Project is completed and 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 analysis, Con Edison concluded that the fair value of its investment in MVP declined below its carrying value and the decline is 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 to reduce the carrying value of its investment in MVP from $662 million to $342 million. The impairment was recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison will not record non-cash equity in earnings from allowance for funds used during construction, if any, from MVP beginning in 2021 and until such time as substantial construction activities are resumed, which would be indicative of probable Project completion. 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, 2020 and 2019: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 CET Gas investment in Stagecoach Gas Services, LLC $845 $924 $— $— CET Gas investment in Mountain Valley Pipeline, LLC (a) 342 602 — — Supplemental retirement income plan assets (b) 465 397 439 371 Deferred income plan assets 92 81 92 81 CET Electric investment in New York Transco, LLC 69 59 — — Other 3 2 10 9 Total investments $1,816 $2,065 $541 $461 (a) At December 31, 2020 and 2019, CET Gas' cash investment in MVP was $530 million. In January 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is continuing to target an in-service date for the Project of late 2021 at an overall Project cost of $5,800 million to $6,000 million, excluding allowance for funds used during construction. For the year ended December 31, 2020, CET Gas owned an 11.3 percent interest in MVP and reduced the carrying value of its investment in MVP from $662 million to $342 million by recognizing a noncash impairment loss of $320 million, pre-tax ($223 million, after tax), and based on total estimated Project costs and CET Gas’ previous capping of its cash contributions to the joint venture, its ownership interest in the joint venture is expected to be reduced to 8.8%. (b) See Note E. 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 New York 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. Upon enactment of the Tax Cuts and Jobs Act of 2017 on December 22, 2017 (the TCJA), the Companies re-measured their deferred tax assets and liabilities based upon the 21 percent corporate income tax rate under the TCJA. The tax effects of changes in tax laws are to be recognized in the period in which the law is enacted and deferred tax assets and liabilities are to be re-measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. For the Utilities, in accordance with their New York rate plans and the accounting rules for regulated operations, the change in deferred taxes was recorded as either an offset to a regulatory asset or a regulatory liability. For Con Edison’s other businesses, the change in deferred taxes was reflected as a decrease in income tax expense, which increased Con Edison's net income. See “Other Regulatory Matters” and “Regulatory Assets and Liabilities” in Note B and Note L. Accumulated deferred investment tax credits are amortized rat

Regulatory Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2020
Regulated Operations [Abstract]
Regulatory Matters	Regulatory Matters Rate Plans The Utilities provide service to New York customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary, are approved by the NJBPU. The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator. Common provisions of the Utilities’ New York rate plans include: 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. Cost 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. Positive revenue adjustments 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). The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2017 – December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b) Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d) 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 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively. 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, the company recorded $34 million primarily related to earnings adjustment mechanism incentives for energy efficiency. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, the company deferred for recovery from customers $242 million of 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 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million. 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. Cost 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 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively. 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, the company deferred $288 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively. 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: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020. Average rate base Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Weighted average cost of capital (after-tax) Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent Yr. 1 – 8.50 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold. 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, the company had no earnings sharing above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent 4.63 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 T ) are not necessary. (b) The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (c) Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision 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 ten-year period, including the overall pre-tax rate of return on such costs. (d) 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). (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: Yr 1 - 10.0 basis points; Yr 2 - 7.5 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 30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan. (g) In addition, the NYSPSC staff has commenced a focused operations audit to investigate the income tax accounting of CECONY and other New York utilities. Any NYSPSC-ordered adjustment to CECONY’s income tax accounting will 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. CECONY – Gas Effective period January 2017 - December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d) 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 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations. 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 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020, the company recorded $3 million of earnings adjustment mechanism incentives for energy efficiency. In 2020, the company recorded positive incentives of $13 million. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, the company deferred for recovery from customers $27 million of revenues. 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 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any 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, the company did not record any negative revenue adjustments. Cost 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 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively. 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, the company deferred $91 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability. 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: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020, the company deferred $24.7 million as a regulatory liability. Average rate base Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million Weighted average cost of capital Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent Yr. 1 – 8.40 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold. 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, the company had no earnings above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent 4.63 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 T ) are not necessary. (b) The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. (c) 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. (d) Amounts reflect amortization of the 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) (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. 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 Amortizations to income of net regulatory (assets) and liabilities $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 2020, the company did not record any negative revenue adjustments. Cost reconciliations (c) In 2014, 2015, 2016, 2017, 2018, 2019 and 2020, 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 and $35 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 $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020. 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 (d) 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 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, the company had no earnings above the threshold. 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) Calculated in accordance with the earnings calculation method prescribed in the rate order. O&R New York – Electric Effective period November 2015 - October 2017 (a) January 2019 – December 2021 (d) Base rate changes Yr. 1 – $9.3 million Yr. 2 – $8.8 million Yr. 3 – None Yr. 1 – $13.4 million (e) Yr. 2 – $8.0 million (e) Yr. 3 – $5.8 million (e) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $(8.5) million (b) Yr. 2 – $(9.4) million (b) Yr. 3 – None Yr. 1 – $(1.5) million (f) Yr. 2 – $(1.5) million (f) Yr. 3 – $(1.5) million (f) 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 and 2020, the company recorded $2.6 million and $1.9 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. Revenue decoupling mechanisms In 2015, 2016, 2017 and 2018, the company deferred for the customer’s benefit an immaterial amount, $6.3 million as regulatory liabilities, $11.2 million as regulatory asset and $0.5 million as regulatory asset, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million as regulatory assets. Recoverable energy costs Continuation of current rate recovery of purchased power costs. Continuation of current rate recovery of purchased power costs. Negative revenue adjustments Potential charges (up to $4 million annually) if certain performance targets are not met. In 2015 the company recorded $1.25 million in negative revenue adjustments. In 2016, 2017 and 2018, the company did not record any 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 and 2020, the company did not record any negative revenue adjustments. Cost reconciliations In 2015, 2016 and 2017, the company deferred $0.3 million, $7.4 million and $3.2 million as net decreases to regulatory assets, respectively. In 2018, the company deferred $5 million as a net regulatory asset. Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), major storms, the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $4.3 million and $30.3 million as net regulatory assets. Net utility plant reconciliations Target levels reflected in rates are: Yr. 1 – $928 million (c) Yr. 2 – $970 million (c) The company increased/(reduced) its regulatory asset by $2.2 million, $(1.9) million, $(1.9) million and $1.4 million in 2015, 2016, 2017 and 2018, respectively. 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 (j): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019 and deferred $0.4 million as a regulatory liability in 2020. Average rate base Yr. 1 – $763 million Yr. 2 – $805 million Yr. 3 – $805 million Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent Authorized return on common equity 9.0 percent 9.0 percent Actual return on common equity (k) Yr. 1 – 10.8 percent Yr. 2 – 9.7 percent Yr. 3 – 7.2 percent Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $6.1 million, $0.3 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold. 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 and 2020, earnings did not exceed the earnings threshold. Cost of long-term debt Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent Common equity ratio 48 percent 48 percent (a) Rates determined pursuant to this rate plan continued in effect until the subsequent rate plan became effective. (b) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a 5 year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015. (c) Excludes electric AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2. (d) 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 T ) are not necessary. (e) The electric base rate increases shown above will be implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million. (f) 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. (g) 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. (h) 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. (i) In addition, amounts reflected in rates relating to income taxes and excess deferred federal income tax liability balances will be reconciled (i.e., refunded to or collected from customers) to any final, non-appealable NYSPSC-ordered findings in its investigation of O&R’s income tax accounting. See “Other Regulatory Matters,” in Note B. (j) 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. (k) Calculated in accordance with the earnings calculation method prescribed in the rate order. In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective January 1, 2022, of $24.5 million.

Capitalization

Capitalization	12 Months Ended
	Dec. 31, 2020
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, 2020 and 2019, 342,297,534 and 332,629,597 shares, respectively, of Con Edison common stock were outstanding. At December 31, 2020 and 2019, 235,488,094 million shares of CECONY common stock were outstanding, all of which were owned by Con Edison. At December 31, 2020 and 2019, 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. In May 2019, Con Edison entered into a forward sale agreement relating to 5,800,000 shares of its common stock. In June 2019, the company issued 4,750,000 shares for $400 million upon physical settlement of shares subject to the forward sale agreement. In January 2020, the company issued 1,050,000 shares for $88 million upon physical settlement of the remaining shares subject to the forward sale agreement. In December 2020, Con Edison issued 7,200,000 shares of its common stock resulting in net proceeds of approximately $553 million, after issuance expenses. The net proceeds from the sale of the common shares, together with the net proceeds from the sale of $650 million aggregate principal amount of 0.65 percent debentures due 2023, were used to prepay in full a $820 million July 2020 term loan. The remaining net proceeds from the sale of the common shares were invested by Con Edison in its subsidiaries, principally CECONY and O&R, and for other general corporate purposes. 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 T . 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 2021-2025 is as follows: (Millions of Dollars) Con Edison CECONY 2021 $1,967 $640 2022 437 — 2023 966 — 2024 385 250 2025 315 — CECONY has issued $450 million of tax – exempt debt through the New York State Energy Research and Development Authority (NYSERDA) that currently bear 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, 2020 and 2019 are: (Millions of Dollars) 2020 2019 Long-Term Debt (including current portion) (a) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $22,349 $26,808 $19,973 $22,738 CECONY $16,789 $20,974 $14,964 $17,505 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020 and $178 million and $151 million for Con Edison and CECONY, respectively, as of December 31, 2019. The fair values of the Companies' long-term debt have been estimated primarily using available market information and at December 31, 2020 are classified as Level 2 (see Note Q). Significant Debt Covenants The significant debt covenants under the financing arrangements for the Companies' debentures and Con Edison's notes and February 2019 $825 million ($675 million of which was outstanding at December 31, 2020) variable-rate term loan that matures in June 2021 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. In addition, the notes include a covenant that the company shall continue its utility business in New York City, the term loan includes a covenant that, subject to certain exceptions, the company and its subsidiaries will not mortgage, lien, pledge or otherwise encumber its assets, and the notes and term loan provide that the company shall not permit its ratio of consolidated debt to consolidated total capital to exceed certain amounts (0.675 to 1 for the notes and 0.65 for the term loan) and include cross default provisions with respect to the failure by the company or any material subsidiary to make one or more payments in respect of material financial obligations (in excess of an aggregate $100 million of debt for the notes and $150 million of debt or derivative obligations for the term loan, excluding non-recourse debt) of the company (or any of its material subsidiaries, in the case of the notes) and the occurrence of an event or condition which results in the acceleration of the maturity of any material debt (in excess of an aggregate $100 million for the notes and $150 million for the term loan, not including non-recourse debt) of the company (or any of its material subsidiaries, in the case of the notes) or enables the holders of such debt to accelerate the maturity thereof. 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, 2020. 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, 2020
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 is 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. At December 31, 2020, Con Edison had $1,705 million of commercial paper outstanding, of which $1,660 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2020 was 0.3 percent for both Con Edison and CECONY. At December 31, 2019, Con Edison had $1,692 million of commercial paper outstanding of which $1,137 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2019 was 2.0 percent for both Con Edison and CECONY. At December 31, 2020 and 2019, no loans were outstanding under the Credit Agreement. An immaterial amount of letters of credit were outstanding under the Credit Agreement as of December 31, 2020 and 2019. The banks’ commitments under the 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, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and 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, 2020 this ratio was 0.53 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 covenants at December 31, 2020. In December 2020, a subsidiary of the Clean Energy Businesses borrowed $165 million under a $613 million variable-rate construction loan facility that matures no later than November 2021, (the Construction Loan Facility) and that is secured by and was used to fund construction costs for three of the company’s solar electric production projects. The banks’ commitments under the Construction Loan Facility are subject to certain conditions, including, among other customary conditions, demonstration of construction progress, that there be no event of default and no material adverse effect. The subsidiary of the Clean Energy Businesses was in compliance with its covenants at December 31, 2020. See Note T for information about short-term borrowing between related parties.

Pension Benefits

Pension Benefits	12 Months Ended
	Dec. 31, 2020
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 2020, 2019 and 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 Service cost – including administrative expenses $293 $250 $290 $274 $232 $272 Interest cost on projected benefit obligation 549 601 561 515 564 525 Expected return on plan assets (1,034) (988) (1,033) (980) (936) (979) Recognition of net actuarial loss 699 518 688 661 492 651 Recognition of prior service credit (16) (17) (17) (19) (19) (19) TOTAL PERIODIC BENEFIT COST $491 $364 $489 $451 $333 $450 Cost capitalized (130) (108) (127) (123) (102) (119) Reconciliation to rate level (250) (15) (92) (239) (12) (100) Total expense recognized $111 $241 $270 $89 $219 $231 In March 2017, the FASB issued amendments to the guidance for retirement benefits through ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The Companies adopted ASU 2017-07 beginning on January 1, 2018. The guidance requires 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. In August 2018, the FASB issued amendments to the guidance for retirement benefits through ASU 2018-14, “Compensation-Retirement Benefits (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans." The guidance requires 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. The Companies adopted ASU 2018-14 for fiscal years ending after December 15, 2020 and the required disclosures are included below and, as applicable, in Note F. Funded Status The funded status at December 31, 2020, 2019 and 2018 was as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $16,792 $14,449 $15,536 $15,750 $13,542 $14,567 Service cost – excluding administrative expenses 288 245 286 269 228 267 Interest cost on projected benefit obligation 549 601 561 515 564 525 Net actuarial loss/(gain) 2,281 2,191 (1,219) 2,154 2,076 (1,159) Plan amendments — 15 — — — — Benefits paid (945) (709) (715) (867) (660) (658) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $18,965 $16,792 $14,449 $17,821 $15,750 $13,542 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $15,608 $13,450 $14,274 $14,790 $12,744 $13,519 Actual return on plan assets 1,927 2,556 (536) 1,830 2,425 (507) Employer contributions 475 350 473 435 318 434 Benefits paid (945) (709) (715) (867) (660) (658) Administrative expenses (43) (39) (46) (41) (37) (44) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $17,022 $15,608 $13,450 $16,147 $14,790 $12,744 FUNDED STATUS $(1,943) $(1,184) $(999) $(1,674) $(960) $(798) Unrecognized net loss $3,330 $2,604 $2,464 $3,145 $2,466 $2,338 Unrecognized prior service costs/(credits) (156) (173) (205) (183) (202) (222) Accumulated benefit obligation 16,768 15,015 13,030 15,676 14,010 12,161 The increase in the pension funded status liability at December 31, 2020 for Con Edison and CECONY of $759 million and $714 million, respectively, compared with December 31, 2019, was primarily due to an increase in the plan's projected benefit obligation as a result of a decrease in the discount rate. The increase in the pension funded status liability at December 31, 2019 for Con Edison and CECONY of $185 million and $162 million, respectively, compared with December 31, 2018, was primarily due to an increase in the plan’s projected benefit obligation as a result of a decrease in the discount rate, partially offset by an increase in 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 determination of the discount rate assumption. For Con Edison, the 2020 increase in pension funded status liability corresponds with an increase to regulatory assets of $734 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, a debit to OCI of $8 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 CECONY, the increase in the pension funded status liability at December 31, 2020 corresponds with an increase to regulatory assets of $696 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, and also a debit to OCI of $2 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, 2020 and 2019, Con Edison’s investments included $465 million and $397 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 $371 million, respectively. See Note Q. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $414 million and $377 million as of December 31, 2020, respectively, and $395 million and $360 million as of December 31, 2019, respectively. Assumptions The actuarial assumptions were as follows: 2020 2019 2018 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 2.55 % 3.35 % 4.25 % Interest crediting rate for cash balance plan 3.00 % 3.30 % 4.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 4.25 % O&R 3.20 % 3.20 % 4.00 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount rate 3.35 % 4.25 % 3.70 % Interest crediting rate for cash balance plan 3.30 % 4.00 % 4.10 % Expected return on plan assets 7.00 % 7.00 % 7.50 % Rate of compensation increase CECONY 3.80 % 4.25 % 4.25 % O&R 3.20 % 4.00 % 4.00 % 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 yields on selected highly rated (Aa or higher by either Moody’s or S&P) corporate bonds. Bonds with insufficient liquidity, 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), and the amount of the bond issue outstanding must be in excess of $50 million. 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) 2021 2022 2023 2024 2025 2026-2030 Con Edison $764 $776 $793 $807 $821 $4,295 CECONY 706 718 733 747 760 3,992 Expected Contributions Based on estimates as of December 31, 2020, the Companies expect to make contributions to the pension plans during 2021 of $480 million (of which $441 million is to be made by CECONY). The Companies’ policy is to fund the total periodic benefit cost 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 2020, 2019 and 2018, and the target allocation for 2021 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2021 2020 2019 2018 Equity Securities 45% - 55% 51 % 51 % 51 % Debt Securities 33% - 43% 38 % 38 % 39 % Real Estate 10% - 14% 11 % 11 % 10 % Total 100% 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 Management Development and Compensation Committee of the Board of Directors (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 2021 reflects the results of such a study conducted in 2018. 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 and report to the Committee regarding, asset class performance, total fund performance, and compliance with asset allocation guidelines. Management changes fund managers and rebalances the portfolio as appropriate. At the direction of the named fiduciaries, such changes are reported to the Committee. Assets measured at fair value on a recurring basis are summarized below as defined by the accounting rules for fair value measurements (see Note Q). The fair values of the pension plan assets at December 31, 2020 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,202 $— $4,202 International Equity (b) 3,693 — 3,693 U.S. Government Issued Debt (c) — 1,424 1,424 Corporate Bonds Debt (d) — 3,535 3,535 Structured Assets Debt (e) — 188 188 Other Fixed Income Debt (f) — 1,067 1,067 Cash and Cash Equivalents (g) 51 408 459 Total investments within the fair value hierarchy $7,946 $6,622 $14,568 Investments measured at NAV per share (m) Private Equity (h) 635 Real Estate (i) 1,880 Hedge Funds (j) 292 Total investments valued using NAV per share $2,807 Funds for retiree health benefits (k) (116) (97) (213) Funds for retiree health benefits measured at NAV per share (k)(m) (41) Total funds for retiree health benefits $(254) Investments (excluding funds for retiree health benefits) $7,830 $6,525 $17,121 Pending activities (l) (99) Total fair value of plan net assets $17,022 (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) Private Equity consists of global equity funds that are not exchange-traded. (i) Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type. (j) Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments. (k) 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. (l) 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. (m) 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, 2019 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $3,652 $— $3,652 International Equity (b) 3,354 — 3,354 U.S. Government Issued Debt (c) — 1,496 1,496 Corporate Bonds Debt (d) — 3,260 3,260 Structured Assets Debt (e) — 173 173 Other Fixed Income Debt (f) — 955 955 Cash and Cash Equivalents (g) — 326 326 Total investments within the fair value hierarchy $7,006 $6,210 $13,216 Investments measured at NAV per share (m) Private Equity (h) 555 Real Estate (i) 1,806 Hedge Funds (j) 270 Total investments valued using NAV per share $2,631 Funds for retiree health benefits (k) (110) (98) (208) Funds for retiree health benefits measured at NAV per share (k)(m) (42) Total funds for retiree health benefits $(250) Investments (excluding funds for retiree health benefits) $6,896 $6,112 $15,597 Pending activities (l) 11 Total fair value of plan net assets $15,608 (a) - (m) Reference is made to footnotes (a) through (m) in the above table of pension plan assets at December 31, 2020 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) 2020 2019 2018 Con Edison $52 $49 $45 CECONY 43 42 39

Other Postretirement Benefits

Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2020
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 2020, 2019 and 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 Service cost $21 $18 $20 $16 $13 $14 Interest cost on accumulated other postretirement benefit obligation 37 44 42 31 36 34 Expected return on plan assets (66) (66) (73) (54) (54) (63) Recognition of net actuarial loss/(gain) 37 (9) 8 36 (10) 3 Recognition of prior service credit (3) (2) (6) (2) (2) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $26 $(15) $(9) $27 $(17) $(14) Cost capitalized (9) (7) (8) (7) (5) (6) Reconciliation to rate level (17) 12 8 (25) 7 9 Total credit recognized $— $(10) ($9) $(5) $(15) ($11) For information about the adoption of ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” and ASU 2018-14, “Compensation-Retirement Benefits (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans," see Note E. Funded Status The funded status of the programs at December 31, 2020, 2019 and 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,357 $1,114 $1,219 $1,154 $913 $985 Service cost 21 18 20 16 13 14 Interest cost on accumulated postretirement benefit obligation 37 44 42 31 36 34 Amendments — (14) — — — — Net actuarial loss/(gain) 74 264 (70) 63 252 (32) Benefits paid and administrative expenses, net of subsidies (117) (110) (135) (107) (100) (125) Participant contributions 53 41 38 52 40 37 BENEFIT OBLIGATION AT END OF YEAR $1,425 $1,357 $1,114 $1,209 $1,154 $913 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,026 $885 $1,039 $872 $759 $893 Actual return on plan assets 142 198 (66) 117 165 (54) Employer contributions 7 7 6 4 6 6 Employer group waiver plan subsidies 20 23 34 19 22 32 Participant contributions 53 40 37 51 40 37 Benefits paid (133) (127) (165) (123) (120) (155) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $1,115 $1,026 $885 $940 $872 $759 FUNDED STATUS $(310) $(331) $(229) $(269) $(282) $(154) Unrecognized net loss/(gain) $115 $155 $14 $114 $149 $(2) Unrecognized prior service costs (16) (19) (8) (1) (3) (5) The decrease in the other postretirement benefits funded status liability at December 31, 2020 for Con Edison and CECONY of $21 million and $13 million, respectively, compared with December 31, 2019, was primarily due to an increase in the fair value of plan assets as a result of the actual return on plan assets, partially offset by an increase in the plans' projected benefit obligation as a result of a decrease in the discount rate. See below for further information on the change in the discount rate and see Note E for determination of the discount rate assumption. The increase in the other postretirement benefits funded status liability at December 31, 2019 for Con Edison and CECONY of $102 million and $128 million, respectively, compared with December 31, 2018, was primarily due to an increase in the plans' projected benefit obligation as a result of an increase in net actuarial loss, partially offset by an increase in plan assets as a result of the actual return on plan assets. For Con Edison, the decrease in funded status liability at December 31, 2020 corresponds with a net decrease to regulatory assets of $36 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, 2020 corresponds with a decrease to regulatory assets of $33 million for unrecognized net losses and the unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, and immaterial changes to OCI for the unrecognized net losses and 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: 2020 2019 2018 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 2.25 % 3.10 % 4.15 % O&R 2.55 % 3.35 % 4.30 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 3.10 % 4.15 % 3.55 % O&R 3.35 % 4.30 % 3.70 % Expected Return on Plan Assets 6.80 % 6.80 % 7.50 % 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 rate used to determine net periodic benefit cost for the years ended December 31, 2020, 2019 and 2018 was 5.20 percent, 5.40 percent and 5.60 percent, respectively, which was assumed to decrease gradually to 4.50 percent by 2024 and remain at that level thereafter. The health care cost trend rate used to determine benefit obligations as of December 31, 2020, 2019 and 2018 was 7.04 percent, 5.20 percent and 5.40 percent, respectively, which is assumed to decrease gradually to 4.50 percent by 2034 and remain at that level thereafter. 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) 2021 2022 2023 2024 2025 2026-2030 Con Edison $84 $84 $84 $84 $84 $409 CECONY 76 75 75 75 75 358 Expected Contributions Based on estimates as of December 31, 2020, Con Edison and CECONY expect to make a contribution of $6 million (of which $3 million is expected to be made by CECONY) to the other postretirement benefit plans in 2021. 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 2020, 2019 and 2018, and the target allocation for 2021 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2021 2020 2019 2018 Equity Securities 42%-80% 54 % 54 % 52 % Debt Securities 20%-58% 46 % 46 % 48 % 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, 2020 by asset category as defined by the accounting rules for fair value measurements (see Note Q) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $448 $448 Other Fixed Income Debt (b) — 367 367 Cash and Cash Equivalents (c) — 27 27 Total investments $— $842 $842 Funds for retiree health benefits (d) 116 97 213 Investments (including funds for retiree health benefits) $116 $939 $1,055 Funds for retiree health benefits measured at net asset value (d)(e) 41 Pending activities (f) 19 Total fair value of plan net assets $1,115 (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, 2019 by asset category (see Note Q) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $404 $404 Other Fixed Income Debt (b) — 331 331 Cash and Cash Equivalents (c) — 23 23 Total investments $— $758 $758 Funds for retiree health benefits (d) 110 98 208 Investments (including funds for retiree health benefits) $110 $856 $966 Funds for retiree health benefits measured at net asset value (d)(e) 42 Pending activities (f) 18 Total fair value of plan net assets $1,026

Environmental Matters

Environmental Matters	12 Months Ended
	Dec. 31, 2020
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, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Accrued Liabilities: Manufactured gas plant sites $752 $640 $676 $561 Other Superfund Sites 105 94 104 93 Total $857 $734 $780 $654 Regulatory assets $865 $732 $791 $647 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, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Remediation costs incurred $33 $19 $32 $13 Insurance and other third party recoveries received by Con Edison or CECONY were immaterial in 2020 and 2019. Con Edison and CECONY estimate that in 2021 they will incur costs for remediation of approximately $40 million and $38 million, respectively. The Companies are unable to estimate the time period over which the remaining accrued liability will be incurred because, among other things, the required remediation has not been determined for some of the sites. In 2020, 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 $2,700 million and $2,600 million, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different. Asbestos Proceedings Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, 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, 2020, 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 for the Companies at December 31, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $72 $78 $68 $73 Regulatory assets/(liabilities) – workers’ compensation $(3) $3 $(3) $3

Material Contingencies

Material Contingencies	12 Months Ended
	Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Material Contingencies	10 years Total (Millions of Dollars) Con Edison Transmission $393 $177 $— $570 Energy transactions 480 51 222 753 Renewable electric production projects 285 9 355 649 Other 70 — — 70 Total $1,228 $237 $577 $2,042 Con Edison Transmission – Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric 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 Electric’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 Production Projects – Con Edison and the Clean Energy Businesses guarantee payments 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. In October 2020, the company accrued a $40 million liability for damages and a $40 million insurance receivable related to the incident. For information about material contingencies, see “Other Regulatory Matters” in Note B, “Superfund Sites” and “Asbestos Proceedings” in Note G and "Uncertain Tax Positions" in Note L. 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 under these agreements totaled $2,042 million and $1,831 million at December 31, 2020 and 2019, respectively. A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2020 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) Con Edison Transmission $393 $177 $— $570 Energy transactions 480 51 222 753 Renewable electric production projects 285 9 355 649 Other 70 — — 70 Total $1,228 $237 $577 $2,042 Con Edison Transmission – Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric 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 Electric’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 Production Projects – Con Edison and the Clean Energy Businesses guarantee payments associated with their investment in, or development for others of, solar and wind energy facilities.

Electricity Purchase Agreements

Electricity Purchase Agreements	12 Months Ended
	Dec. 31, 2020
Regulated Operations [Abstract]
Electricity Purchase Agreements	Regulatory Matters Rate Plans The Utilities provide service to New York customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary, are approved by the NJBPU. The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator. Common provisions of the Utilities’ New York rate plans include: 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. Cost 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. Positive revenue adjustments 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). The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2017 – December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b) Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d) 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 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively. 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, the company recorded $34 million primarily related to earnings adjustment mechanism incentives for energy efficiency. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, the company deferred for recovery from customers $242 million of 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 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million. 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. Cost 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 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively. 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, the company deferred $288 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively. 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: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020. Average rate base Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Weighted average cost of capital (after-tax) Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent Yr. 1 – 8.50 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold. 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, the company had no earnings sharing above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent 4.63 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 T ) are not necessary. (b) The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (c) Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision 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 ten-year period, including the overall pre-tax rate of return on such costs. (d) 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). (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: Yr 1 - 10.0 basis points; Yr 2 - 7.5 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 30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan. (g) In addition, the NYSPSC staff has commenced a focused operations audit to investigate the income tax accounting of CECONY and other New York utilities. Any NYSPSC-ordered adjustment to CECONY’s income tax accounting will 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. CECONY – Gas Effective period January 2017 - December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d) 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 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations. 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 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020, the company recorded $3 million of earnings adjustment mechanism incentives for energy efficiency. In 2020, the company recorded positive incentives of $13 million. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, the company deferred for recovery from customers $27 million of revenues. 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 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any 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, the company did not record any negative revenue adjustments. Cost 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 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively. 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, the company deferred $91 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability. 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: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020, the company deferred $24.7 million as a regulatory liability. Average rate base Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million Weighted average cost of capital Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent Yr. 1 – 8.40 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold. 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, the company had no earnings above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent 4.63 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 T ) are not necessary. (b) The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. (c) 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. (d) Amounts reflect amortization of the 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) (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. 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 Amortizations to income of net regulatory (assets) and liabilities $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 2020, the company did not record any negative revenue adjustments. Cost reconciliations (c) In 2014, 2015, 2016, 2017, 2018, 2019 and 2020, 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 and $35 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 $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020. 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 (d) 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 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, the company had no earnings above the threshold. 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) Calculated in accordance with the earnings calculation method prescribed in the rate order. O&R New York – Electric Effective period November 2015 - October 2017 (a) January 2019 – December 2021 (d) Base rate changes Yr. 1 – $9.3 million Yr. 2 – $8.8 million Yr. 3 – None Yr. 1 – $13.4 million (e) Yr. 2 – $8.0 million (e) Yr. 3 – $5.8 million (e) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $(8.5) million (b) Yr. 2 – $(9.4) million (b) Yr. 3 – None Yr. 1 – $(1.5) million (f) Yr. 2 – $(1.5) million (f) Yr. 3 – $(1.5) million (f) 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 and 2020, the company recorded $2.6 million and $1.9 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. Revenue decoupling mechanisms In 2015, 2016, 2017 and 2018, the company deferred for the customer’s benefit an immaterial amount, $6.3 million as regulatory liabilities, $11.2 million as regulatory asset and $0.5 million as regulatory asset, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million as regulatory assets. Recoverable energy costs Continuation of current rate recovery of purchased power costs. Continuation of current rate recovery of purchased power costs. Negative revenue adjustments Potential charges (up to $4 million annually) if certain performance targets are not met. In 2015 the company recorded $1.25 million in negative revenue adjustments. In 2016, 2017 and 2018, the company did not record any 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 and 2020, the company did not record any negative revenue adjustments. Cost reconciliations In 2015, 2016 and 2017, the company deferred $0.3 million, $7.4 million and $3.2 million as net decreases to regulatory assets, respectively. In 2018, the company deferred $5 million as a net regulatory asset. Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), major storms, the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $4.3 million and $30.3 million as net regulatory assets. Net utility plant reconciliations Target levels reflected in rates are: Yr. 1 – $928 million (c) Yr. 2 – $970 million (c) The company increased/(reduced) its regulatory asset by $2.2 million, $(1.9) million, $(1.9) million and $1.4 million in 2015, 2016, 2017 and 2018, respectively. 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 (j): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019 and deferred $0.4 million as a regulatory liability in 2020. Average rate base Yr. 1 – $763 million Yr. 2 – $805 million Yr. 3 – $805 million Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent Authorized return on common equity 9.0 percent 9.0 percent Actual return on common equity (k) Yr. 1 – 10.8 percent Yr. 2 – 9.7 percent Yr. 3 – 7.2 percent Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $6.1 million, $0.3 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold. 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 and 2020, earnings did not exceed the earnings threshold. Cost of long-term debt Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent Common equity ratio 48 percent 48 percent (a) Rates determined pursuant to this rate plan continued in effect until the subsequent rate plan became effective. (b) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a 5 year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015. (c) Excludes electric AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2. (d) 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 T ) are not necessary. (e) The electric base rate increases shown above will be implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million. (f) 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. (g) 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. (h) 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. (i) In addition, amounts reflected in rates relating to income taxes and excess deferred federal income tax liability balances will be reconciled (i.e., refunded to or collected from customers) to any final, non-appealable NYSPSC-ordered findings in its investigation of O&R’s income tax accounting. See “Other Regulatory Matters,” in Note B. (j) 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. (k) Calculated in accordance with the earnings calculation method prescribed in the rate order. In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective January 1, 2022, of $24.5 million.

Leases

Leases	12 Months Ended
	Dec. 31, 2020
Leases [Abstract]
Leases	Leases In January 2019, the Companies adopted Accounting Standards Update (ASU) No. 2016-02, “Leases (Topic 842),” including the amendments thereto, using a modified retrospective transition method of adoption that required no prior period adjustments or charges to retained earnings for cumulative impact. The standard supersedes the lease requirements within ASC Topic 840, “Leases.” The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognized 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 are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases. For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 40 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, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Operating lease cost $85 $83 $65 $64 Operating lease cash flows $79 $75 $61 $60 As of December 31, 2020, assets recorded as finance leases for Con Edison and CECONY were $3 million and $2 million, respectively, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively. As of December 31, 2019, assets recorded as finance leases were $1 million for Con Edison and an immaterial amount for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $5 million and $3 million, respectively. For the twelve months ended December 31, 2020 and 2019, 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 $23 million and $11 million, respectively, for the twelve months ended December 31, 2020 and $39 million and $4 million, respectively, for the twelve months ended December 31, 2019. Other information related to leases for Con Edison and CECONY at December 31, 2020 and 2019 was as follows: Con Edison CECONY 2020 2019 2020 2019 Weighted Average Remaining Lease Term: Operating leases 19.1 years 19.8 years 13.0 years 14.0 years Finance leases 7.3 years 12.2 years 4.0 years 2.4 years Weighted Average Discount Rate: Operating leases 4.3% 4.3% 3.6% 3.6% Finance leases 1.8% 3.5% 1.3% 4.1% Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, Operating Leases Finance Leases Operating Leases Finance Leases 2021 $79 $1 $62 $1 2022 77 1 58 1 2023 74 — 57 — 2024 75 — 57 — 2025 75 — 58 — All years thereafter 938 1 451 — Total future minimum lease payments $1,318 $3 $743 $2 Less: imputed interest (458) — (158) — Total $860 $3 $585 $2 Reported as of December 31, 2020 Operating lease liabilities (current) $96 $— $73 $— Operating lease liabilities (noncurrent) 764 — 512 — Other current liabilities — 1 — 1 Other noncurrent liabilities — 2 — 1 Total $860 $3 $585 $2 At December 31, 2020, the Companies did not have material obligations under operating or finance leases that had not yet commenced.
Leases	Leases In January 2019, the Companies adopted Accounting Standards Update (ASU) No. 2016-02, “Leases (Topic 842),” including the amendments thereto, using a modified retrospective transition method of adoption that required no prior period adjustments or charges to retained earnings for cumulative impact. The standard supersedes the lease requirements within ASC Topic 840, “Leases.” The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognized 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 are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases. For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 40 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, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Operating lease cost $85 $83 $65 $64 Operating lease cash flows $79 $75 $61 $60 As of December 31, 2020, assets recorded as finance leases for Con Edison and CECONY were $3 million and $2 million, respectively, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively. As of December 31, 2019, assets recorded as finance leases were $1 million for Con Edison and an immaterial amount for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $5 million and $3 million, respectively. For the twelve months ended December 31, 2020 and 2019, 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 $23 million and $11 million, respectively, for the twelve months ended December 31, 2020 and $39 million and $4 million, respectively, for the twelve months ended December 31, 2019. Other information related to leases for Con Edison and CECONY at December 31, 2020 and 2019 was as follows: Con Edison CECONY 2020 2019 2020 2019 Weighted Average Remaining Lease Term: Operating leases 19.1 years 19.8 years 13.0 years 14.0 years Finance leases 7.3 years 12.2 years 4.0 years 2.4 years Weighted Average Discount Rate: Operating leases 4.3% 4.3% 3.6% 3.6% Finance leases 1.8% 3.5% 1.3% 4.1% Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, Operating Leases Finance Leases Operating Leases Finance Leases 2021 $79 $1 $62 $1 2022 77 1 58 1 2023 74 — 57 — 2024 75 — 57 — 2025 75 — 58 — All years thereafter 938 1 451 — Total future minimum lease payments $1,318 $3 $743 $2 Less: imputed interest (458) — (158) — Total $860 $3 $585 $2 Reported as of December 31, 2020 Operating lease liabilities (current) $96 $— $73 $— Operating lease liabilities (noncurrent) 764 — 512 — Other current liabilities — 1 — 1 Other noncurrent liabilities — 2 — 1 Total $860 $3 $585 $2 At December 31, 2020, the Companies did not have material obligations under operating or finance leases that had not yet commenced.

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2020
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 gas storage company by CET Gas, and the acquisitions of a residential solar company and battery storage company by the Clean Energy Businesses. In 2020 and 2019, Con Edison completed impairment tests for their 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 2019, the Companies performed the optional qualitative assessment for goodwill related to the O&R merger. In 2020 and 2019, Con Edison completed impairment tests for goodwill of $8 million related to the gas storage company acquired by CET Gas, $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, and determined that they were not impaired. 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, 2020.

Income Tax

Income Tax	12 Months Ended
	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Income Tax	Income Tax In response to the economic impacts of the COVID-19 pandemic, the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) was signed into law on March 27, 2020. The CARES Act provides relief to corporate taxpayers by permitting a five-year carryback of net operating losses (NOLs) for tax years 2018, 2019 and 2020, temporarily removing the 80 percent limitation when applying the NOLs to carryback years, increasing the 30 percent limitation on interest deductibility to 50 percent of adjusted taxable income for tax years 2019 and 2020, and provides for certain employee retention tax credits and refunds for eligible employers. Under the CARES Act, Con Edison carried back its $29 million NOL from tax year 2018 to tax year 2013 generating a $2.5 million net tax refund for which a tax receivable was established in 2020. In addition, Con Edison recognized a discrete income tax benefit of $4 million in 2020, due to the higher federal statutory tax rate in 2013. The 2018 federal NOL was recorded at 21 percent and was carried back to tax year 2013, which had a 35 percent federal statutory tax rate. This income tax benefit was primarily recognized at the Clean Energy Businesses. The components of income tax are as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 State Current $7 $(12) $(10) $6 $22 $6 Deferred 50 96 107 97 68 82 Federal Current (2) — 3 41 185 (34) Deferred 42 219 310 73 63 275 Amortization of investment tax credits (7) (7) (9) (2) (3) (3) Total income tax expense $90 $296 $401 $215 $335 $326 The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Deferred tax liabilities: Property basis differences $7,985 $7,699 $6,901 $6,640 Regulatory assets: Unrecognized pension and other postretirement costs 910 712 861 674 Environmental remediation costs 243 205 222 181 Deferred storm costs 31 22 — — Other regulatory assets 536 376 508 355 Operating lease right-of-use asset 220 231 165 169 Equity investments 46 104 — — Total deferred tax liabilities $9,971 $9,349 $8,657 $8,019 Deferred tax assets: Accrued pension and other postretirement costs $504 $291 $427 $222 Regulatory liabilities: Future income tax 617 678 579 638 Other regulatory liabilities 656 702 570 622 Superfund and other environmental costs 241 206 219 183 Asset retirement obligations 178 135 143 102 Operating lease liabilities 211 231 165 170 Loss carryforwards 164 108 34 — Tax credits carryforward 1,022 896 — — Valuation allowance (22) (31) — — Other 59 47 127 103 Total deferred tax assets 3,630 3,263 2,264 2,040 Net deferred tax liabilities $6,341 $6,086 $6,393 $5,979 Unamortized investment tax credits 134 141 18 21 Net deferred tax liabilities and unamortized investment tax credits $6,475 $6,227 $6,411 $6,000 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) 2020 2019 2018 2020 2019 2018 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 4 4 4 5 5 5 Taxes attributable to noncontrolling interests (1) (1) — — — — Cost of removal 2 1 1 1 1 1 Other plant-related items (1) (1) (1) (1) (1) (1) TCJA deferred tax re-measurement — — 2 — — — Amortization of excess deferred federal income taxes (14) (4) (3) (12) (4) (3) Renewable energy credits (3) (2) (1) — — — Research and development credits — (1) — — (1) (1) Other (1) — — 1 — (1) Effective tax rate 7 % 17 % 23 % 15 % 21 % 21 % CECONY and O&R deferred as regulatory liabilities their estimated net benefits under the TCJA for the year ended December 31, 2018. CECONY’s net benefits prior to January 1, 2019 for its electric service and amortization of excess deferred federal income taxes for its electric service continued to be deferred. RECO deferred as a regulatory liability its estimated net benefits under the TCJA for the three months ended March 31, 2018. The net benefits include the revenue requirement impact of the reduction in the corporate federal income tax rate to 21 percent, the elimination for utilities of bonus depreciation and the amortization of excess deferred federal income taxes the utilities collected from customers that will not be paid to the IRS under the TCJA. See “Other Regulatory Matters” in Note B. At December 31, 2020, Con Edison has a federal NOL of approximately $21 million that can be carried forward indefinitely. Con Edison also has $1,022 million in general business tax credit carryovers (primarily renewable energy tax credits), which if unused will begin to expire in 2032. 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, 2020, Con Edison has a New York State NOL of approximately $1,351 million, primarily as a result of higher accelerated state tax depreciation. A deferred tax asset has been recognized for these New York State NOL carryforwards that will begin to expire, if unused, in 2039 and no valuation allowance was provided; as it is more likely than not that the deferred tax asset will be realized. In addition, Con Edison reversed $9 million of the valuation allowance against the New York City NOL deferred tax asset that will be realized over the next 10 years. Con Edison also has a $18 million valuation allowance for other state NOL carryforwards; as it is not more likely than not that the deferred tax asset will be realized. The Protecting Americans from Tax Hikes Act of 2015 extended bonus depreciation applying a 50 percent rate for property acquired and placed in service for years 2015 through 2017 with reduced rates of 40 percent and 30 percent for years 2018 and 2019, respectively. The TCJA does not allow bonus depreciation after December 31, 2017 (excluding certain transition rules) for Companies that qualify as a utility company for the consolidated group under the de minimis exception to Treasury regulations. In December 2019, the Federal government issued final regulations providing guidance on provisions in the TCJA allowing for full expensing of qualified plant additions. These provisions, which Con Edison adopted under the proposed regulations of August 2018, allowed the Utilities a full expense tax deduction for plant additions in the fourth quarter of 2017, and the Utilities continue additional first year depreciation transition rules for plant additions placed in service in tax years beginning in 2018, under long-term construction contracts entered into before September 28, 2017. The impact on the Utilities of these regulations is discussed above. In November 2018, the Federal government issued, and Con Edison adopted, proposed regulations providing guidance on the tax deductibility of interest expense under the TCJA. The TCJA generally provides for the continued deductibility of interest expense by regulated public utilities and may limit the deduction for interest expense by most non-utility businesses to 30 percent of adjusted taxable income (which resembles earnings before interest, taxes, depreciation and amortization).The regulations provide an annual safe harbor test that if at least 90 percent of consolidated plant assets consist of utility property, the entire consolidated group will be treated as a regulated public utility, and all of the consolidated group’s interest expense will be currently tax deductible. For 2018, Con Edison met the 90 percent safe harbor test and its deduction for interest expense was not limited. For 2019, Con Edison did not meet the 90 percent safe harbor test, however, its deduction for interest expense was not limited as a percentage of adjusted taxable income. In 2020, the federal government issued final regulations under the TCJA. Under the CARES Act, the limit of the deductible interest expense as a percentage of adjusted taxable income increased from 30 percent to 50 percent and accordingly, all of Con Edison’s interest expense in 2020 will be tax deductible. Qualifying consolidated groups would not be entitled to the full expensing provisions in the TCJA noted above. The safe harbor rules do not apply to partnerships in which Con Edison and its subsidiaries are a partner. 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) 2020 2019 2018 2020 2019 2018 Balance at January 1, $13 $6 $12 $2 $4 $5 Additions based on tax positions related to the current year — 1 2 — 1 2 Additions based on tax positions of prior years 1 10 1 1 — 1 Reductions for tax positions of prior years — (2) (2) — (1) (1) Reductions from expiration of statute of limitations — — (4) — — — Settlements — (2) (3) — (2) (3) Balance at December 31, $14 $13 $6 $3 $2 $4 At December 31, 2020, the estimated liability for uncertain tax positions for Con Edison was $14 million ($3 million for CECONY). Con Edison reasonably expects to resolve within the next twelve months approximately $3 million of various federal and state 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 $1 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 $14 million ($13 million, net of federal taxes) with $3 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. For the year ended December 31, 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, 2020 and 2019, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets. Con Edison's federal tax return for 2019 remains under examination. State and local income tax returns remain open for examination in New York State for tax years 2010 through 2019, in New Jersey for tax years 2016 through 2019 and in New York City for tax years 2015 and 2019.

Revenue Recognition

Revenue Recognition	12 Months Ended
	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition The following table presents, for the years ended December 31, 2020 and 2019, 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. 2020 2019 2018 (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 $8,026 $77 $8,103 $7,913 $149 $8,062 $7,920 $51 $7,971 Gas 1,998 38 2,036 2,097 35 2,132 2,052 26 2,078 Steam 494 14 508 610 17 627 625 6 631 Total CECONY $10,518 $129 $10,647 $10,620 $201 $10,821 $10,597 $83 $10,680 O&R Electric 619 10 629 627 7 634 647 (5) 642 Gas 224 9 233 247 12 259 256 (7) 249 Total O&R $843 $19 $862 $874 $19 $893 $903 $(12) $891 Clean Energy Businesses Renewables 609 (b) — 609 575 (b) — 575 329 (b) — 329 Energy services 52 — 52 71 — 71 95 — 95 Other — 75 75 — 211 211 — 339 339 Total Clean Energy Businesses $661 $75 $736 $646 $211 $857 $424 $339 $763 Con Edison Transmission 4 — 4 4 — 4 4 — 4 Other (c) — (3) (3) — (1) (1) — (1) (1) Total Con Edison $12,026 $220 $12,246 $12,144 $430 $12,574 $11,928 $409 $12,337 (a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans. For the Clean Energy Businesses, this includes revenue from wholesale services. (b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $8 million, $14 million and $103 million for the years ended December 31, 2020, 2019 and 2018, respectively, of revenue related to engineering, procurement and construction services. (c) Parent company and consolidation adjustments. 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 production 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. 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. 2020 2019 2018 (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, $29 $17 $29 $20 $58 $87 Additions (c) 88 31 86 1 144 38 Subtractions (c) 106 7 (d) 86 4 (d) 173 105 (d) Ending balance as of December 31, $11 $41 $29 $17 $29 $20 (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, $7 million, $4 million and $50 million were included in the balances as of January 1, 2020, 2019, and 2018, respectively. As of December 31, 2020, the aggregate amount of the remaining fixed performance obligations of the Clean Energy Businesses under contracts with customers for energy services is $216 million, of which $181 million will be recognized within the next two years, and the remaining $35 million will be recognized pursuant to long-term service and maintenance agreements. In March 2020, the Utilities began suspending new late payment charges and certain other fees for all customers. The estimated amount of these foregone revenues for the year ended December 31, 2020 was $64 million and $61 million for Con Edison and CECONY, respectively. 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. See "COVID-19 Regulatory Matters" in Note B.

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2020
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. 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, 2020 were new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2021. 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, 2020, 2019 and 2018: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 Performance-based restricted stock $7 $36 $3 $6 $30 $3 Time-based restricted stock 1 2 2 1 2 1 Non-employee director deferred stock compensation 2 2 3 2 2 3 Stock purchase plan 7 7 6 7 6 6 Total $17 $47 $14 $16 $40 $13 Income tax benefit $5 $13 $4 $4 $11 $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 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, for 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: 2020 2019 2018 Risk-free interest rate (a) 0.10% - 0.13% 1.58% - 1.59% 2.48% -2.63% Expected term (b) 3 years 3 years 3 years Expected share price volatility (c) 30.16% - 40.95% 12.89% - 15.51% 14.76% - 17.71% (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. A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2020 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, 2019 991,238 $68.15 $77.14 742,204 $68.06 $77.32 Granted 329,600 79.98 90.48 249,761 79.70 89.65 Vested (326,496) 73.07 74.57 (245,269) 72.70 74.76 Forfeited (92,818) 73.80 87.98 (60,225) 73.61 87.73 Non-vested at December 31, 2020 901,524 $70.11 $81.83 686,471 $70.15 $81.80 (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, 2020 is $21 million, including $17 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 $21 million and $18 million in 2020, $24 million and $22 million in 2019, and $29 million and $28 million in 2018, 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 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, 2020 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, 2019 67,250 $80.36 63,100 $80.36 Granted 22,450 78.00 20,900 78.00 Vested (20,750) 77.66 (19,650) 77.66 Forfeited (1,512) 80.30 (1,512) 80.30 Non-vested at December 31, 2020 67,438 $80.40 62,838 $80.42 The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2020 for Con Edison and CECONY was $2 million and is expected to be recognized over a weighted average period of one year. Con Edison and CECONY paid cash of $1 million in 2020, 2019 and 2018, 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, 2020, approximately 33,200 units were issued at a weighted average grant date price of $74.32. 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 2020, 2019 and 2018, 836,984, 747,899 and 786,385 shares were purchased under the Stock Purchase Plan at a weighted average price of $79.82, $85.45 and $78.27 per share, respectively.

Financial Information by Busine

Financial Information by Business Segment	12 Months Ended
	Dec. 31, 2020
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, 2020 (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 $8,103 $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 $616 Con Edison Transmission 4 — 1 (8) (215) 18 — 1,348 3 Other (b) (3) — — (10) (5) 25 (3) 485 — Total Con Edison $12,246 $— $1,920 $2,654 $(401) $1,019 $193 $62,895 $4,085 As of and for the Year Ended December 31, 2019 (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 $8,062 $17 $1,053 $1,758 $(28) $539 $239 $32,988 $1,851 Gas 2,132 7 231 528 (4) 147 99 11,090 1,078 Steam 627 70 89 62 (3) 42 4 2,479 91 Consolidation adjustments — (94) — — — — — — — Total CECONY $10,821 $— $1,373 $2,348 $(35) $728 $342 $46,557 $3,020 O&R Electric $634 $— $60 $98 $(7) $27 $15 $2,130 $142 Gas 259 — 24 41 (4) 14 6 876 61 Other — — — — — — — — — Total O&R $893 $— $84 $139 $(11) $41 $21 $3,006 $203 Clean Energy Businesses $857 $— $226 $202 $5 $186 $(58) $6,528 $248 Con Edison Transmission 4 — 1 (6) 104 25 1 1,618 205 Other (b) (1) — — (7) (12) 11 (6) 370 — Total Con Edison $12,574 $— $1,684 $2,676 $51 $991 $300 $58,079 $3,676 As of and for the Year Ended December 31, 2018 (Millions of Dollars) Operating Inter- Depreciation Operating Other Income (deductions) Interest Income Total Capital CECONY Electric $7,971 $16 $984 $1,799 $(110) $519 $233 $31,012 $1,861 Gas 2,078 7 205 478 (23) 131 87 9,710 1,050 Steam 631 75 87 77 (10) 39 8 2,386 94 Consolidation adjustments — (98) — — — — — — — Total CECONY $10,680 $— $1,276 $2,354 $(143) $689 $328 $43,108 $3,005 O&R Electric $642 $— $56 $93 $(14) $25 $14 $2,036 $138 Gas 249 — 21 39 (5) 14 7 856 67 Other — — — — — — — — — Total O&R $891 $— $77 $132 $(19) $39 $21 $2,892 $205 Clean Energy Businesses $763 $— $85 $194 $33 $63 $19 $5,821 $1,791 Con Edison Transmission 4 — 1 (7) 91 20 (1) 1,425 248 Other (b) (1) — (1) (9) (24) 8 39 674 — Total Con Edison $12,337 $— $1,438 $2,664 $(62) $819 $406 $53,920 $5,249 (a) For Con Edison, the income tax expense/(benefit) on non-operating income was $(103) million, $(4) million and $(5) million in 2020, 2019 and 2018, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(3) million, $(7) million and $(2) million in 2020, 2019 and 2018, respectively. (b) 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, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. These are economic hedges, for which the Utilities and the Clean Energy Business do not elect hedge accounting. The Clean Energy Businesses use interest rate swaps to manage the risks associated with interest rates related to outstanding and expected future debt issuances and borrowings. Derivatives are recognized on the consolidated balance sheet at fair value (see Note Q), 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. In August 2017, the FASB issued amendments to the guidance for derivatives and hedging through ASU 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities.” The amendments in this update provide greater clarification on hedge accounting for risk components, presentation and disclosure of hedging instruments, and overall targeted improvements to simplify hedge accounting. The amendments were effective for reporting periods beginning after December 15, 2018. The application of the guidance did not have a material impact on the Companies’ financial position, results of operations and liquidity because the Companies do not elect hedge accounting for their derivative instruments and hedging activities. The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2020 and 2019 were: (Millions of Dollars) 2020 2019 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 $44 $14 $58 (b) $60 $(3) $57 (b) Noncurrent 22 35 57 19 (13) 6 (d) Total fair value of derivative assets $66 $49 $115 $79 $(16) $63 Fair value of derivative liabilities Current $(225) $(13) $(238) (c) $(140) $17 $(123) (d) Noncurrent (207) (33) (240) (c) (122) 16 (106) (d) Total fair value of derivative liabilities $(432) $(46) $(478) $(262) $33 $(229) Net fair value derivative assets/(liabilities) $(366) $3 $(363) $(183) $17 $(166) CECONY Fair value of derivative assets Current $20 $(12) $8 (b) $39 $(6) $33 (b) Noncurrent 16 (8) 8 17 (12) 5 Total fair value of derivative assets $36 $(20) $16 $56 $(18) $38 Fair value of derivative liabilities Current $(174) $11 $(163) $(100) $19 $(81) Noncurrent (114) 9 (105) (80) 16 (64) Total fair value of derivative liabilities $(288) $20 $(268) $(180) $35 $(145) Net fair value derivative assets/(liabilities) $(252) $— $(252) $(124) $17 $(107) (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, 2020 and 2019, margin deposits for Con Edison ($3 million and $9 million, respectively) and CECONY ($3 million and $8 million, 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 $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps range from 2024-2041. (d) Includes amounts for interest rate swaps of $1 million in current assets, $(7) million in current liabilities and $(34) million in noncurrent liabilities. At December 31, 2019, the Clean Energy Businesses had interest rate swaps with notional amounts of $919 million. The expiration dates of the swaps range from 2024-2041. 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 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 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, 2020 and 2019: Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2020 2019 2020 2019 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $(26) $4 $(27) $5 Noncurrent Deferred derivative gains — (3) — (1) Total deferred gains/(losses) $(26) $1 $(27) $4 Current Deferred derivative losses $(63) $(91) $(64) $(83) Current Recoverable energy costs (201) (142) (177) (124) Noncurrent Deferred derivative losses (37) (67) (36) (65) Total deferred gains/(losses) $(301) $(300) $(277) $(272) Net deferred gains/(losses) $(327) $(299) $(304) $(268) Income Statement Location Pre-tax gain/(loss) recognized in income Gas purchased for resale $(2) $(2) $— $— Non-utility revenue 7 25 — — Other operations and maintenance expense (3) 1 (3) 1 Other interest expense (65) (36) — — Total pre-tax gain/(loss) recognized in income $(63) $(12) $(3) $1 The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2020: Electric Energy (MWh) (a)(b) Capacity (MW) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 28,102,230 47,258 286,819,910 7,728,000 CECONY 26,193,800 35,400 267,380,000 7,728,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes. The Companies are exposed to credit risk related to transactions entered into primarily for the various energy supply and hedging activities by the Utilities 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, 2020, Con Edison and CECONY had $217 million and $16 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 $103 million with independent system operators, $47 million with investment-grade counterparties, $40 million with non-investment grade/non-rated counterparties, and $27 million with commodity exchange brokers. CECONY’s net credit exposure consisted of $16 million with commodity exchange brokers. The collateral requirements associated with, and settlement of, derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated 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, 2020: (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $293 $277 Collateral posted 212 200 Additional collateral (b) (downgrade one level from current ratings) 5 — Additional collateral (b)(c) (downgrade to below investment grade from current ratings) 101 85 (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 $25 million at December 31, 2020. 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, 2020, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $51 million.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2020
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, 2020 and 2019 are summarized below. 2020 2019 (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) $19 $42 $4 $53 $118 $4 $61 $2 $4 $71 Interest rate swaps (a)(b)(c)(f) — — — — — — 1 — — 1 Other (a)(b)(d) 431 126 — — 557 353 125 — — 478 Total assets $450 $168 $4 $53 $675 $357 $187 $2 $4 $550 Derivative liabilities: Commodity (a)(b)(c) $7 $296 $23 $46 $372 $18 $174 $18 $(22) $188 Interest rate swaps (a)(b)(c)(f) — 106 — — 106 — 41 — — 41 Total liabilities $7 $402 $23 $46 $478 $18 $215 $18 $(22) $229 CECONY Derivative assets: Commodity (a)(b)(c) $15 $20 $— $(16) $19 $3 $42 $1 $— $46 Other (a)(b)(d) 411 120 — — 531 333 119 — — 452 Total assets $426 $140 $— $(16) $550 $336 $161 $1 $— $498 Derivative liabilities: Commodity (a)(b)(c) $3 $274 $10 $(19) $268 $15 $147 $7 $(24) $145 (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 $1 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2020 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, 2020 to less than three years as of December 31, 2020. Con Edison and CECONY had $24 million and $22 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2019 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of December 31, 2017 to less than three years as of December 31, 2019. (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, 2020 and 2019, 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 P. 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 on a monthly basis 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, 2020 (Millions of Dollars) Valuation Techniques Unobservable Inputs Range Con Edison — Commodity Electricity (20) Discounted Cash Flow Forward capacity prices (a) $0.06-$6.26 per kW-month Transmission Congestion Contracts/Financial Transmission Rights 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $(2.65)-$7.69 per MWh Total Con Edison — Commodity $(19) CECONY — Commodity Electricity $(11) Discounted Cash Flow Forward capacity prices (a) $0.08-$6.26 per kW-month Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.23-$1.13 per MWh Total CECONY — Commodity $(10) (a) Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement. (b) Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement. The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the years ended December 31, 2020 and 2019 and classified as Level 3 in the fair value hierarchy: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Beginning balance as of January 1, $(16) $(13) $(6) $(2) Included in earnings (10) (5) (5) — Included in regulatory assets and liabilities (7) 18 (4) 17 Settlements 15 8 6 1 Transfer out of level 3 (1) (24) (1) (22) Ending balance as of December 31, $(19) $(16) $(10) $(6) 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 ($3 million gain and $2 million gain) on the consolidated income statement for the years ended December 31, 2020 and 2019, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at December 31, 2020 and 2019 is included in non-utility revenues ($2 million gain) on the consolidated income statement for the years ended December 31, 2020 and 2019.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2020
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 2020, 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. In April 2017, CECONY's long-term electricity purchase agreement with Cogen Technologies Linden Venture, LP (Linden Cogeneration), another potential VIE, expired. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY's maximum exposure to loss with respect to the potential VIEs. Clean Energy Businesses In September 2019, the Clean Energy Businesses, which previously owned an 80 percent membership interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), acquired the remaining 20 percent interest. As a result of the acquisition, Texas Solar 4 is a consolidated entity. Prior to the acquisition, Con Edison had a variable interest in Texas Solar 4, as to which Con Edison was the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 was held by the Clean Energy Businesses. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project. Electricity generated by the project is sold pursuant to a long-term power purchase agreement. Con Edison's earnings from Texas Solar 4 for the years ended December 31, 2019 and 2018 were immaterial. In December 2018, the Clean Energy Businesses completed its acquisition of Sempra Solar Holdings, LLC. See Note V. 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. For the year ended December 31, 2020, the hypothetical liquidation at book value (HLBV) method of accounting for the Tax Equity Projects resulted in $44 million of income ($32 million, after tax) for the tax equity investor and a $6 million loss ($4 million, after tax) for Con Edison. For the year ended December 31, 2019, the HLBV method of accounting for the Tax Equity Projects resulted in $98 million of income ($74 million, after tax) for the tax equity investor and a $64 million loss ($48 million, after tax) for Con Edison, and earnings under the HLBV method for the year ended December 31, 2018 were immaterial. Con Edison has determined that the use of HLBV accounting is reasonable and appropriate to attribute income and loss to the tax equity investors. Using the HLBV method, the company's earnings from the projects are adjusted to reflect the income or loss allocable to the tax equity investors calculated based on how the project would allocate and distribute its cash if it were to sell all of its assets for their carrying amounts and liquidate at a particular point in time. Under the HLBV method, the company calculates the liquidation value allocable to the tax equity investors at the beginning and end of each period based on the contractual liquidation waterfall and adjusts its income for the period to reflect the change in the liquidation value allocable to the tax equity investors. At December 31, 2020 and 2019, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs: Tax Equity Projects Great Valley Solar Copper Mountain - Mesquite Solar (Millions of Dollars) 2020 2019 2020 2019 Non-utility property, less accumulated depreciation (f)(g) 284 293 446 461 Other assets 39 40 176 128 Total assets (a) $323 $333 $622 $589 Other liabilities 13 17 71 18 Total liabilities (b) $13 $17 $71 $18 (a) The assets of the Tax Equity Projects represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE. (b) The liabilities of the Tax Equity Projects represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. (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 $82 million and $62 million at December 31, 2020 and 2019, 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 $134 million and $126 million at December 31, 2020 and 2019, respectively. (f) Non-utility property is reduced by accumulated depreciation of $18 million for Great Valley Solar and $30 million for Copper Mountain - Mesquite Solar at December 31, 2020. (g) Non-utility property is reduced by accumulated depreciation of $9 million for Great Valley Solar, $15 million for Copper Mountain - Mesquite Solar at December 31, 2019. The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2020: 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 California $228 Copper Mountain - Mesquite Solar (c) 344 20-25 2018 Nevada and Arizona 417 (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 and Copper Mountain Mesquite Solar, refer to (d) and (e) in the table above.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2020
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 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. At December 31, 2020, the liabilities for asset retirement obligations of Con Edison and CECONY were $576 million and $508 million, respectively. At December 31, 2019, the liabilities for asset retirement obligations of Con Edison and CECONY were $425 million and $362 million, respectively. The change in liabilities at December 31, 2020 was due to changes in estimated cash flows of $191 million and $186 million for Con Edison and CECONY, respectively, and accretion expense of $16 million and $13 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $56 million and $53 million for Con Edison and CECONY, respectively. The change in liabilities at December 31, 2019 was due to changes in estimated cash flows of $(1) million and $96 million for Con Edison and CECONY, respectively, and accretion expense of $14 million and $12 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $38 million for both Con Edison and CECONY. Con Edison and CECONY also recorded reductions of $49 million and $44 million during the years ended December 31, 2020 and 2019, 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, 2020
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 ($14,849 million and $807 million, respectively), at December 31, 2020, 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, 2020, 2019 and 2018 were as follows: CECONY (Millions of Dollars) 2020 2019 2018 Cost of services provided $128 $121 $115 Cost of services received 66 64 73 In addition, CECONY and O&R have joint gas supply arrangements in connection with which CECONY sold to O&R $59 million, $71 million and $83 million of natural gas for the years ended December 31, 2020, 2019 and 2018, respectively. These amounts are net of the effect of related hedging transactions. The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric 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, 2020 and 2019, the amounts billed by the Utilities to NY Transco were immaterial. 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 formed by a subsidiary of CET Gas 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 $34 million, $33 million and $28 million for the years ended December 31, 2020, 2019 and 2018, respectively. CECONY has a 20-year transportation contract with Mountain Valley Pipeline, LLC (MVP) for 250,000 dekatherms per day of capacity. CET Gas owns an 11.3 percent equity interest in MVP (that is expected to be reduced to 8.8 percent). See "Investments" 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, 2020 and 2019, 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, 2020 and 2019 there were no outstanding loans to O&R. The Clean Energy Businesses had financial electric capacity contracts with CECONY and O&R during 2020 and 2019. For the years ended December 31, 2020 and 2019, the Clean Energy Businesses realized an immaterial loss and a $1 million loss, respectively, under these contracts.

New Financial Accounting Standa

New Financial Accounting Standards	12 Months Ended
	Dec. 31, 2020
Accounting Changes and Error Corrections [Abstract]
New Financial Accounting Standards	New Financial Accounting Standards In December 2019, the FASB issued amendments to the guidance for income taxes through ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” The amendments in this update simplify the accounting for income taxes by removing certain exceptions such as: 1) the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, 2) the requirement to recognize a deferred tax liability for equity method investments when a foreign subsidiary becomes an equity method investment, 3) the ability not to recognize a deferred tax liability for a foreign subsidiary when a foreign equity method investment becomes a subsidiary, and 4) the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. For public entities, the amendments are effective for reporting periods beginning after December 15, 2020. Early adoption is permitted. The application of this guidance will not have a material impact on the Companies’ financial position, results of operations and liquidity. 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. In November 2020, LIBOR’s administrator announced it plans to consult on its intention to cease publication of one-week and two-month U.S. Dollar LIBOR immediately after the LIBOR publication on December 31, 2021, and the remaining U.S. Dollar LIBOR tenors immediately after publication on June 30, 2023. 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

Acquisitions, Investments and D

Acquisitions, Investments and Dispositions	12 Months Ended
	Dec. 31, 2020
Business Combinations [Abstract]
Acquisitions, Investments and Dispositions	Acquisitions and Investments Sempra Solar In December 2018, the Clean Energy Businesses completed their acquisition of Sempra Solar Holdings, LLC, a Sempra Energy subsidiary, for $1,609 million, including working capital and other closing adjustments of $69 million. In 2019, Con Edison finalized the purchase price allocation and reclassified approximately $100 million which primarily decreased property, plant and equipment and asset retirement obligations, the impact of which was not material to earnings. The reclassification was recorded within the one year available to finalize the purchase price allocation. The acquired company has ownership interests in 981 megawatts (AC) of operating renewable electric production projects, including its 379 megawatts (AC) share of projects in which its subsidiaries had a 50 percent ownership interest (Acquired JV Interests) and the Clean Energy Businesses had the remaining ownership interests (Previously-Owned JV Interests), and certain development rights with respect to solar electric production and energy storage projects. At the acquisition date, the acquired company’s subsidiaries had $1,354 million of tangible assets consisting mostly of property, plant and equipment, $878 million of intangible assets mostly arising from power purchase agreements, $4 million of other noncurrent assets, $568 million of project debt (including, in each case, amounts associated with the Acquired JV Interests) and $28 million of asset retirement obligation liabilities. The weighted average amortization period for these intangible assets is 16 years. At the acquisition date, the fair value of the noncontrolling interest attributable to the tax equity investors (see below) was $100 million. The acquisition date valuation was performed using a discounted cash flow approach . The fair values of assets acquired and liabilities assumed were determined based on significant estimates and assumptions that are judgmental in nature, including projected amounts and timing of future cash flows, discount rates reflecting risk inherent in the future cash flows and future power prices. Upon completion of the acquisition, the acquisition date fair value of the Previously-Owned JV Interests increased from $437 million to $568 million and Con Edison recognized a pre-tax gain of $131 million ($89 million or $0.28 per share net of taxes). Prior to the acquisition, Con Edison had been accounting for the Previously-Owned JV Interests under the equity method. Upon completion of the acquisition, Con Edison is accounting for Acquired JV Interests and the Previously-Owned JV Interests on a consolidated basis. Certain projects acquired have tax equity investors to which a percentage of earnings, tax attributes and cash flows are allocated. See Note R. Con Edison's revenues and net income for the years ended December 31, 2018 and 2017 as reported and pro forma to account on a consolidated basis for the acquisition as if the acquisition had been completed on January 1, 2017 instead of December 13, 2018 are as follows: Years ended December 31, (Millions of Dollars) 2018 2017 As Reported Revenue $12,337 $12,033 Net income 1,382 1,525 PRO FORMA SUPPLEMENTAL INFORMATION If Acquired January 1, 2017 (a)(b) Revenue $12,655 $12,331 Net income 1,279 1,612 (a) Reflects the following material adjustments: • included additional interest expense of $37 million and $38 million in 2018 and 2017, respectively, that would have been incurred if $825 million that was borrowed in December 2018 under a variable rate term loan agreement to fund a portion of the purchase price for the acquisition had instead been borrowed for such purpose on January 1, 2017 at a fixed rate of 4.64% per annum; and • with respect to the Previously-Owned JV Interests: eliminated the $131 million purchase accounting gain (pre-tax) that Con Edison recognized upon the completion of the acquisition in 2018 and reflected the $131 million purchase accounting gain in 2017; recorded the corresponding increase to the book value of the related net utility plant and power purchase agreement intangible asset as of January 1, 2017 instead of December 13, 2018, and included the increased depreciation and amortization expense in 2018 and 2017; and eliminated $33 million and $32 million of other income that Con Edison had recorded in 2018 and 2017, respectively, under the equity method of accounting. (b) Recalculating each investor’s claim on the investee’s assets under the contractual liquidation waterfall as if the acquisition had been completed on January 1, 2017 is impracticable. Accordingly, no HLBV adjustments were made.

Schedule I - Condensed Financia

Schedule I - Condensed Financial Information	12 Months Ended
	Dec. 31, 2020
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Financial Information	Schedule I Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Statement of Income and Comprehensive Income (Parent Company Only) For the Years Ended December 31, (Millions of Dollars, except per share amounts) 2020 2019 2018 Equity in earnings of subsidiaries $1,105 $1,354 $1,447 Other income (deductions), net of taxes 56 76 (6) Interest expense (60) (87) (59) Net Income $1,101 $1,343 $1,382 Comprehensive Income $1,095 $1,340 $1,392 Net Income Per Share – Basic $3.29 $4.09 $4.43 Net Income Per Share – Diluted $3.28 $4.08 $4.42 Dividends Declared Per Share $3.06 $2.96 $2.86 Average Number Of Shares Outstanding—Basic (In Millions) 334.8 328.5 311.1 Average Number Of Shares Outstanding—Diluted (In Millions) 335.7 329.5 312.9 (a) These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above. Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Statement of Cash Flows (Parent Company Only) For the Years Ended December 31, (Millions of Dollars) 2020 2019 2018 Net Income 1,101 1,343 1,382 Equity in earnings of subsidiaries (1,105) (1,354) (1,447) Dividends received from: CECONY 982 912 846 O&R 49 47 46 Clean Energy Businesses 21 3 15 Con Edison Transmission 11 12 10 Change in Assets: Special deposits — (3) (8) Income taxes receivable — 25 2 Other – net 654 44 187 Net Cash Flows from Operating Activities 1,713 1,029 1,033 Investing Activities Contributions to subsidiaries (626) (930) (1,110) Debt receivable from affiliated companies 400 450 (825) Net Cash Flows Used in Investing Activities (226) (480) (1,935) Financing Activities Net proceeds of short-term debt (537) (783) 164 Issuance of long-term debt 650 825 825 Retirement of long-term debt (1,178) (553) (3) Debt issuance costs (3) — — Issuance of common shares for stock plans, net of repurchases 58 54 53 Issuance of common shares - public offering 640 825 705 Common stock dividends (975) (924) (842) Net Cash Flows Used in Financing Activities (1,345) (556) 902 Net Change for the Period 142 (7) — Balance at Beginning of Period 2 9 9 Balance at End of Period $144 $2 $9 (a) These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above. Condensed Financial Information of Consolidated Edison, Inc. (a) Condensed Balance Sheet (Parent Company Only) December 31, (Millions of Dollars) 2020 2019 Assets Current Assets Cash and temporary cash investments $144 $2 Accounts receivable - other 1 Income taxes receivable 18 18 Term loan receivable from affiliated companies — — Accounts receivable from affiliated companies 1,256 870 Prepayments 62 32 Other current assets 12 12 Total Current Assets 1,493 934 Investments in subsidiaries and others 18,670 18,009 Goodwill 406 406 Deferred income tax 55 14 Long-term debt receivable from affiliated companies 875 1,275 Other noncurrent assets — — Total Assets $21,499 $20,638 Liabilities and Shareholders’ Equity Current Liabilities Long-term debt due within one year $1,178 $3 Term loan — — Notes payable — 537 Accounts payable — — Accounts payable to affiliated companies 517 595 Accrued taxes 6 2 Other current liabilities 12 10 Total Current Liabilities 1,713 1,147 Deferred income tax — — Total Liabilities 1,713 1,147 Long-term debt 939 1,469 Shareholders’ Equity Common stock, including additional paid-in capital 8,844 8,089 Retained earnings 10,003 9,933 Total Shareholders’ Equity 18,847 18,022 Total Liabilities and Shareholders’ Equity $21,499 $20,638 (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.

Schedule II - Valuation and Qua

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2020
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, 2020, 2019 and 2018 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): 2020 $74 $72 $— $8 $154 2019 $68 $77 $— $(71) $74 2018 $70 $62 $— $(64) $68 CECONY Allowance for uncollectible accounts (a): 2020 $68 $65 $— $10 $143 2019 $61 $72 $— $(65) $68 2018 $65 $56 $— $(60) $61 (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, 2020
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 R), 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, 2020 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by state regulators.
Financial Instruments - Credit Losses	Financial Instruments – Credit Losses Adoption of New Standard In January 2020, the Companies adopted Accounting Standards Update (ASU) 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendments replace the incurred loss impairment methodology which involved delayed recognition of credit losses. The amendments introduce an expected credit loss impairment model which requires immediate recognition of anticipated losses over the instrument’s life. A broader range of reasonable and supportable information must be considered in developing the credit loss estimates. The Companies' financial instruments subject to the amendments are included in the lines “Accounts receivable – customers” and “Other receivables.” Substantially all of these in-scope financial instruments are expected to be collected within one year of billing. The Companies adopted the amendments using the modified retrospective method for all financial instruments measured at amortized costs. Results for reporting periods beginning after January 1, 2020 are presented under Accounting Standards Codification (ASC) 326 while prior period amounts continue to be reported in accordance with previously applicable GAAP. No prior period adjustment or charge to retained earnings for cumulative impact was required as a result of the Companies’ adoption of the amendments. 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’ other receivables balance includes bills related to the sale of energy from renewable electric production projects. 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, 2020. 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. During the year of 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 $78 million and $73 million, respectively, for the year ended December 31, 2020. 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.
Revenues	Revenues CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism, that covers all residential and most commercial customers, under which the company’s actual energy delivery revenues are compared with the authorized delivery revenues and the difference accrued, with interest, for refund to, or recovery from, customers, as applicable. See “Rate Plans” in Note B.
Plant and Depreciation Utility Plant	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 S. 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, 5.1 percent and 5.4 percent for 2020, 2019 and 2018, respectively. The AFUDC rates for O&R were 5.3 percent, 5.3 percent and 2.2 percent for 2020, 2019 and 2018, 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 2020 and 3.2 percent for 2019 and 2018. The average depreciation rates for O&R were 3.2 percent for 2020, 3.0 percent for 2019 and 2.9 percent for 2018. The estimated lives for utility plant for CECONY range from 5 to 85 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 production 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. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on these assets 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
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 and costs of its electric demand management programs 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 periodically evaluate its investments 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 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 involves 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 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. Con Edison evaluated its equity method investments and determined that there was an other-than-temporary decline in the value of its investment in Mountain Valley Pipeline LLC (MVP) and therefore recorded a partial impairment at December 31, 2020, as described below. Also, Con Edison is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC (Stagecoach), a joint venture that owns and operates an existing gas pipeline and storage business located in northeastern Pennsylvania and the southern tier of New York. As such strategic alternatives are evaluated, Con Edison may be required to determine whether an other-than-temporary decline in value has occurred for its Stagecoach investment. Partial Impairment of Investment in Mountain Valley Pipeline LLC (MVP) In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET Gas), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed gas transmission project (the Project) in West Virginia and Virginia. At December 31, 2020 and 2019, CET Gas' cash contributions to MVP were approximately $530 million, and the carrying value at December 31, 2020 prior to recording an impairment loss was $662 million, reflecting CET Gas' proportionate share of allowance for funds used during construction (AFUDC) income from the Project. During 2019, Con Edison determined that, as it was permitted to do under the MVP joint venture agreement, it would limit its cash contributions to the joint venture to approximately $530 million, which limit was reached in 2019, and that is expected to result in the further reduction of Con Edison’s ownership share in the joint venture. At December 31, 2020, CET Gas owned an 11.3 percent interest in MVP that is expected to be reduced to 8.8 percent based on the current project cost estimate and CET Gas’ previous capping of its cash contributions to the joint venture. 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 the first 77 miles of the Project in West Virginia, 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 amendment would lead to additional Project costs and would extend the anticipated in-service date of the Project to late 2021. The uncertainty related to obtaining the necessary permits in lieu of the Nationwide Permit 12, the resulting Project costs and the likelihood of the Project not reaching eventual completion have increased, constituting a triggering event which required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. Further, in January 2021, the FERC did not approve the requested amendment. In its discussion, a FERC commissioner indicated that the commission should have the plan for the entire Project’s water crossings rather than the first 77 miles and that all of the Federal permits be restored before allowing additional construction to resume. 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 certificate amendment for other water crossings that, in total, would cover the entire Project length. In addition, the second largest partner in the Project announced it had recorded a significant impairment of their investment in the Project at year-end 2020. In response to the 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. 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 T. 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. Con Edison believes that the likelihood of Project completion is in the upper end of a reasonably possible range. The likelihood that the Project is completed and 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 analysis, Con Edison concluded that the fair value of its investment in MVP declined below its carrying value and the decline is 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 to reduce the carrying value of its investment in MVP from $662 million to $342 million. The impairment was recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison will not record non-cash equity in earnings from allowance for funds used during construction, if any, from MVP beginning in 2021 and until such time as substantial construction activities are resumed, which would be indicative of probable Project completion. 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 New York 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. Upon enactment of the Tax Cuts and Jobs Act of 2017 on December 22, 2017 (the TCJA), the Companies re-measured their deferred tax assets and liabilities based upon the 21 percent corporate income tax rate under the TCJA. The tax effects of changes in tax laws are to be recognized in the period in which the law is enacted and deferred tax assets and liabilities are to be re-measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. For the Utilities, in accordance with their New York rate plans and the accounting rules for regulated operations, the change in deferred taxes was recorded as either an offset to a regulatory asset or a regulatory liability. For Con Edison’s other businesses, the change in deferred taxes was reflected as a decrease in income tax expense, which increased Con Edison's net income. See “Other Regulatory Matters” and “Regulatory Assets and Liabilities” in Note B and Note L. 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 year amounts have been reclassified within Note L to conform with current year 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 December 2019, the FASB issued amendments to the guidance for income taxes through ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” The amendments in this update simplify the accounting for income taxes by removing certain exceptions such as: 1) the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, 2) the requirement to recognize a deferred tax liability for equity method investments when a foreign subsidiary becomes an equity method investment, 3) the ability not to recognize a deferred tax liability for a foreign subsidiary when a foreign equity method investment becomes a subsidiary, and 4) the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. For public entities, the amendments are effective for reporting periods beginning after December 15, 2020. Early adoption is permitted. The application of this guidance will not have a material impact on the Companies’ financial position, results of operations and liquidity. 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. In November 2020, LIBOR’s administrator announced it plans to consult on its intention to cease publication of one-week and two-month U.S. Dollar LIBOR immediately after the LIBOR publication on December 31, 2021, and the remaining U.S. Dollar LIBOR tenors immediately after publication on June 30, 2023. 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

Summary of Significant Accoun_3

Summary of Significant Accounting Policies and Other Matters (Tables)	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Accounts Receivable, Allowance for Credit Loss	The table below presents a rollforward by major portfolio segment type for the year ended December 31, 2020: For the Year Ended December 31, 2020 Con Edison CECONY (Millions of Dollars) Accounts receivable - customers Other receivables Accounts receivable - customers Other receivables Allowance for credit losses Beginning Balance at January 1, 2020 $70 $4 $65 $3 Recoveries 8 — 6 — Write-offs (54) (2) (50) (1) Reserve adjustments 124 5 117 2 Ending Balance December 31, 2020 $148 $7 $138 $4
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) 2020 2019 2018 Con Edison $335 $323 $330 CECONY 323 312 318
Capitalized Cost of Utility Plant	At December 31, 2020 and 2019, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Electric Generation $572 $591 $572 $591 Transmission 3,786 3,634 3,496 3,380 Distribution 21,481 20,676 20,366 19,602 General 52 43 52 43 Gas (a) 9,206 8,617 8,522 7,961 Steam 1,854 1,813 1,854 1,813 General 2,507 2,365 2,286 2,143 Held for future use 92 75 84 67 Construction work in progress 2,474 1,937 2,320 1,812 Net Utility Plant $42,024 $39,751 $39,552 $37,412 (a) Primarily distribution.
Schedule of Investment Assets	The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2020 and 2019: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 CET Gas investment in Stagecoach Gas Services, LLC $845 $924 $— $— CET Gas investment in Mountain Valley Pipeline, LLC (a) 342 602 — — Supplemental retirement income plan assets (b) 465 397 439 371 Deferred income plan assets 92 81 92 81 CET Electric investment in New York Transco, LLC 69 59 — — Other 3 2 10 9 Total investments $1,816 $2,065 $541 $461 (a) At December 31, 2020 and 2019, CET Gas' cash investment in MVP was $530 million. In January 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is continuing to target an in-service date for the Project of late 2021 at an overall Project cost of $5,800 million to $6,000 million, excluding allowance for funds used during construction. For the year ended December 31, 2020, CET Gas owned an 11.3 percent interest in MVP and reduced the carrying value of its investment in MVP from $662 million to $342 million by recognizing a noncash impairment loss of $320 million, pre-tax ($223 million, after tax), and based on total estimated Project costs and CET Gas’ previous capping of its cash contributions to the joint venture, its ownership interest in the joint venture is expected to be reduced to 8.8%. (b) See Note E.
Research and Development Costs	Research and development costs were as follows: For the Years Ended December 31, (Millions of Dollars) 2020 2019 2018 Con Edison $24 $24 $24 CECONY 23 23 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) 2020 2019 2018 Net income for common stock $1,101 $1,343 $1,382 Weighted average common shares outstanding – basic 334.8 328.5 311.7 Add: Incremental shares attributable to effect of potentially dilutive securities 0.9 1.0 1.2 Adjusted weighted average common shares outstanding – diluted 335.7 329.5 312.9 Net Income per common share – basic $3.29 $4.09 $4.43 Net Income per common share – diluted $3.28 $4.08 $4.42
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, 2017 (a) $(26) $(6) OCI before reclassifications, net of tax of $3 for Con Edison 4 — Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b) 6 1 Total OCI, net of taxes, at December 31, 2018 10 1 Accumulated OCI, net of taxes, at December 31, 2018 (a) $(16) $(5) OCI before reclassifications, net of tax of $(6) and $(1) for Con Edison and CECONY, respectively (10) (3) Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b) 7 2 Total OCI, net of taxes, at December 31, 2019 (3) (1) 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) (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, 2020 and 2019, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows: At December 31, Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Cash and temporary cash investments $1,272 $981 $1,067 $933 Restricted cash (a) 164 236 — — Total cash, temporary cash investments and restricted cash $1,436 $1,217 $1,067 $933 (a) Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($164 million and $236 million at December 31, 2020 and 2019, respectively) that, under the related project debt agreements, is either restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves or, for the December 31, 2019 amount, was restricted as a result of the PG&E bankruptcy. During the pendency of the PG&E bankruptcy, cash was not distributed from the related projects to the Clean Energy Businesses. In July 2020, PG&E's plan of reorganization became effective and the Clean Energy Businesses received previously restricted distributions and have resumed receiving distributions for all projects. See "Long-Lived and Intangible Assets,” above.
Schedule of Cash and Cash Equivalents	At December 31, 2020 and 2019, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows: At December 31, Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Cash and temporary cash investments $1,272 $981 $1,067 $933 Restricted cash (a) 164 236 — — Total cash, temporary cash investments and restricted cash $1,436 $1,217 $1,067 $933 (a) Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($164 million and $236 million at December 31, 2020 and 2019, respectively) that, under the related project debt agreements, is either restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves or, for the December 31, 2019 amount, was restricted as a result of the PG&E bankruptcy. During the pendency of the PG&E bankruptcy, cash was not distributed from the related projects to the Clean Energy Businesses. In July 2020, PG&E's plan of reorganization became effective and the Clean Energy Businesses received previously restricted distributions and have resumed receiving distributions for all projects. See "Long-Lived and Intangible Assets,” above.

Regulatory Matters (Tables)

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2020
Regulated Operations [Abstract]
Summary of Utilities Rate Plans	The following tables contain a summary of the Utilities’ rate plans: CECONY – Electric Effective period January 2017 – December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b) Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d) 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 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively. 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, the company recorded $34 million primarily related to earnings adjustment mechanism incentives for energy efficiency. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, the company deferred for recovery from customers $242 million of 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 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million. 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. Cost 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 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively. 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, the company deferred $288 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively. 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: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020. Average rate base Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million Weighted average cost of capital (after-tax) Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent Yr. 1 – 8.50 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold. 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, the company had no earnings sharing above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent 4.63 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 T ) are not necessary. (b) The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (c) Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision 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 ten-year period, including the overall pre-tax rate of return on such costs. (d) 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). (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: Yr 1 - 10.0 basis points; Yr 2 - 7.5 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 30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan. (g) In addition, the NYSPSC staff has commenced a focused operations audit to investigate the income tax accounting of CECONY and other New York utilities. Any NYSPSC-ordered adjustment to CECONY’s income tax accounting will 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. CECONY – Gas Effective period January 2017 - December 2019 January 2020 – December 2022 (a) Base rate changes Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d) 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 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations. 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 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020, the company recorded $3 million of earnings adjustment mechanism incentives for energy efficiency. In 2020, the company recorded positive incentives of $13 million. Revenue decoupling mechanisms Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, the company deferred for recovery from customers $27 million of revenues. 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 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any 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, the company did not record any negative revenue adjustments. Cost 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 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively. 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, the company deferred $91 million of net regulatory assets. Net utility plant reconciliations Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability. 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: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020, the company deferred $24.7 million as a regulatory liability. Average rate base Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million Weighted average cost of capital Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent 6.61 percent Authorized return on common equity 9.0 percent 8.80 percent Actual return on common equity (i) Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent Yr. 1 – 8.40 percent Earnings sharing Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold. 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, the company had no earnings above the threshold. Cost of long-term debt Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent 4.63 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 T ) are not necessary. (b) The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. (c) 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. (d) Amounts reflect amortization of the 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) (e)-(i) See footnotes (e) - (i) to the table under “CECONY Electric,” above. 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 Amortizations to income of net regulatory (assets) and liabilities $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 2020, the company did not record any negative revenue adjustments. Cost reconciliations (c) In 2014, 2015, 2016, 2017, 2018, 2019 and 2020, 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 and $35 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 $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020. 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 (d) 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 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, the company had no earnings above the threshold. 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) Calculated in accordance with the earnings calculation method prescribed in the rate order. O&R New York – Electric Effective period November 2015 - October 2017 (a) January 2019 – December 2021 (d) Base rate changes Yr. 1 – $9.3 million Yr. 2 – $8.8 million Yr. 3 – None Yr. 1 – $13.4 million (e) Yr. 2 – $8.0 million (e) Yr. 3 – $5.8 million (e) Amortizations to income of net regulatory (assets) and liabilities Yr. 1 – $(8.5) million (b) Yr. 2 – $(9.4) million (b) Yr. 3 – None Yr. 1 – $(1.5) million (f) Yr. 2 – $(1.5) million (f) Yr. 3 – $(1.5) million (f) 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 and 2020, the company recorded $2.6 million and $1.9 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. Revenue decoupling mechanisms In 2015, 2016, 2017 and 2018, the company deferred for the customer’s benefit an immaterial amount, $6.3 million as regulatory liabilities, $11.2 million as regulatory asset and $0.5 million as regulatory asset, respectively. Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million as regulatory assets. Recoverable energy costs Continuation of current rate recovery of purchased power costs. Continuation of current rate recovery of purchased power costs. Negative revenue adjustments Potential charges (up to $4 million annually) if certain performance targets are not met. In 2015 the company recorded $1.25 million in negative revenue adjustments. In 2016, 2017 and 2018, the company did not record any 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 and 2020, the company did not record any negative revenue adjustments. Cost reconciliations In 2015, 2016 and 2017, the company deferred $0.3 million, $7.4 million and $3.2 million as net decreases to regulatory assets, respectively. In 2018, the company deferred $5 million as a net regulatory asset. Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), major storms, the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $4.3 million and $30.3 million as net regulatory assets. Net utility plant reconciliations Target levels reflected in rates are: Yr. 1 – $928 million (c) Yr. 2 – $970 million (c) The company increased/(reduced) its regulatory asset by $2.2 million, $(1.9) million, $(1.9) million and $1.4 million in 2015, 2016, 2017 and 2018, respectively. 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 (j): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019 and deferred $0.4 million as a regulatory liability in 2020. Average rate base Yr. 1 – $763 million Yr. 2 – $805 million Yr. 3 – $805 million Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million Weighted average cost of capital (after-tax) Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent Authorized return on common equity 9.0 percent 9.0 percent Actual return on common equity (k) Yr. 1 – 10.8 percent Yr. 2 – 9.7 percent Yr. 3 – 7.2 percent Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $6.1 million, $0.3 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold. 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 and 2020, earnings did not exceed the earnings threshold. Cost of long-term debt Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent Common equity ratio 48 percent 48 percent (a) Rates determined pursuant to this rate plan continued in effect until the subsequent rate plan became effective. (b) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a 5 year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015. (c) Excludes electric AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2. (d) 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 T ) are not necessary. (e) The electric base rate increases shown above will be implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million. (f) 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. (g) 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. (h) 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. (i) In addition, amounts reflected in rates relating to income taxes and excess deferred federal income tax liability balances will be reconciled (i.e., refunded to or collected from customers) to any final, non-appealable NYSPSC-ordered findings in its investigation of O&R’s income tax accounting. See “Other Regulatory Matters,” in Note B. (j) 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. (k) Calculated in accordance with the earnings calculation method prescribed in the rate order. In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective January 1, 2022, of $24.5 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased power, and the reconciliation of actual expenses allocable to the electric business to the amounts for such costs reflected in electric rates for storm costs, pension and other postretirement benefit costs, environmental remediation and property taxes. O&R New York – Gas Effective period November 2015 – October 2018 (a) January 2019 – December 2021 (d) Base rate changes Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge Yr. 1 – $(7.5) million (e) Yr. 2 – $3.6 million (e) Yr. 3 – $0.7 million (e) Amortization to income of net regulatory (assets) and liabilities Yr. 1 – $(1.7) million (b) Yr. 2 – $(2.1) million (b) Yr. 3 – $(2.5) million (b) Yr. 1 – $1.8 million (f) Yr. 2 – $1.8 million (f) Yr. 3 – $1.8 million (f) Other revenue sources Continuation of retention of annual revenues from non-firm customers of up to $4.0 million, with variances to be shared 80 percent by customers and 20 percent by company. Potential earnings adjustment mechanism incentives of up to $0.3 million annually. Potential incentives if performance targets related to gas leak backlog, leak prone pipe, emergency response, damage prevention and customer service are met: Yr. 1 - $1.2 million; Yr. 2 - $1.3 million; and Yr. 3 - $1.3 million. In 2019 and 2020, the company recorded $0.3 million of earnings adjustment mechanism incentives for energy efficiency. In 2019 and 2020, the company recorded $0.7 million and $0.5 million of positive incentives, respectively. Revenue decoupling mechanisms In 2015, 2016, 2017 and 2018, the company deferred $0.8 million of regulatory assets, $6.2 million of regulatory liabilities, $1.7 million of regulatory liabilities and $6.3 million of regulatory liabilities, respectively. Continuation of reconciliation of actual to authorized gas delivery revenues. In 2019 and 2020, the company deferred $0.8 million and $0.5 million of regulatory assets, respectively. Recoverable energy costs Current rate recovery of purchased gas costs. Continuation of current rate recovery of purchased gas costs. Negative revenue adjustments Potential charges (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $4.9 million in Yr. 3) if certain performance targets are not met. In 2015, 2016 and 2017, the company did not record any negative revenue adjustments. In 2018, the company recorded a $0.1 million negative revenue adjustment. Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $5.5 million; Yr. 2 - $5.7 million; and Yr. 3 - $6.0 million. In 2019 and 2020, the company recorded a $0.2 million and an immaterial amount of negative revenue adjustments, respectively. Cost reconciliations In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively. In 2017 and 2018, the company deferred $3.5 million and $7.4 million as net regulatory liabilities, respectively. Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $6 million as net regulatory liabilities and $1.8 million as net regulatory assets, respectively. Net utility plant reconciliations Target levels reflected in rates are: Yr. 1 – $492 million (c) Yr. 2 – $518 million (c) Yr. 3 – $546 million (c) No deferral was recorded for 2015 and immaterial amounts were recorded as regulatory liabilities in 2016 and 2017. In 2018, the company deferred $0.4 million as regulatory asset. Target levels reflected in rates were: Gas average net plant target excluding AMI: Yr. 1 - $593 million Yr. 2 - $611 million Yr. 3 - $632 million AMI (j): Yr. 1 - $20 million Yr. 2 - $24 million Yr. 3 - $25 million In 2019 and 2020, the company deferred immaterial amounts as regulatory assets. Average rate base Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 mi
Schedule of Regulatory Assets	Regulatory Assets and Liabilities Regulatory assets and liabilities at December 31, 2020 and 2019 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Regulatory assets Unrecognized pension and other postretirement costs $3,241 $2,541 $3,065 $2,403 Environmental remediation costs 865 732 791 647 Revenue taxes 356 321 342 308 Pension and other postretirement benefits deferrals 315 71 272 47 Property tax reconciliation 241 219 239 210 Deferred storm costs 195 77 83 — MTA power reliability deferral 188 248 188 248 System peak reduction and energy efficiency programs 124 131 124 130 Deferred derivative losses 120 83 111 76 COVID - 19 Deferrals 115 — 113 — Municipal infrastructure support costs 62 75 62 75 Brooklyn Queens demand management program 36 39 36 39 Meadowlands heater odorization project 32 35 32 35 Gate station upgrade project 25 19 25 19 Unamortized loss on reacquired debt 21 28 19 26 Preferred stock redemption 21 22 21 22 Recoverable REV demonstration project costs 20 21 18 19 Non-wire alternative projects 18 14 18 14 Workers’ compensation — 3 — 3 Other 200 180 186 166 Regulatory assets – noncurrent 6,195 4,859 5,745 4,487 Deferred derivative losses 190 128 177 113 Recoverable energy costs 76 — 67 — Regulatory assets – current 266 128 244 113 Total Regulatory Assets $6,461 $4,987 $5,989 $4,600 Regulatory liabilities Future income tax* $2,207 $2,426 $2,062 $2,275 Allowance for cost of removal less salvage 1,090 989 932 843 TCJA net benefits 295 471 286 454 Net unbilled revenue deferrals 198 199 198 199 Net proceeds from sale of property 137 173 137 173 Pension and other postretirement benefit deferrals 85 75 46 46 System benefit charge carrying charge 64 48 57 44 Property tax refunds 36 45 35 45 BQDM and REV Demo reconciliations 27 27 25 26 Settlement of gas proceedings 21 10 21 10 Sales and use tax refunds 16 8 16 8 Earnings sharing - electric, gas and steam 15 22 10 15 Unrecognized other postretirement costs 11 9 — — Settlement of prudence proceeding 5 8 5 8 Workers’ compensation 3 — 3 — Energy efficiency portfolio standard unencumbered funds 1 122 — 118 Other 302 195 261 163 Regulatory liabilities – noncurrent 4,513 4,827 4,094 4,427 Refundable energy costs 28 44 4 12 Deferred derivative gains 8 34 7 34 Revenue decoupling mechanism — 24 — 17 Regulatory liabilities—current 36 102 11 63 Total Regulatory Liabilities $4,549 $4,929 $4,105 $4,490 * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.
Schedule of Regulatory Liabilities	Regulatory Assets and Liabilities Regulatory assets and liabilities at December 31, 2020 and 2019 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Regulatory assets Unrecognized pension and other postretirement costs $3,241 $2,541 $3,065 $2,403 Environmental remediation costs 865 732 791 647 Revenue taxes 356 321 342 308 Pension and other postretirement benefits deferrals 315 71 272 47 Property tax reconciliation 241 219 239 210 Deferred storm costs 195 77 83 — MTA power reliability deferral 188 248 188 248 System peak reduction and energy efficiency programs 124 131 124 130 Deferred derivative losses 120 83 111 76 COVID - 19 Deferrals 115 — 113 — Municipal infrastructure support costs 62 75 62 75 Brooklyn Queens demand management program 36 39 36 39 Meadowlands heater odorization project 32 35 32 35 Gate station upgrade project 25 19 25 19 Unamortized loss on reacquired debt 21 28 19 26 Preferred stock redemption 21 22 21 22 Recoverable REV demonstration project costs 20 21 18 19 Non-wire alternative projects 18 14 18 14 Workers’ compensation — 3 — 3 Other 200 180 186 166 Regulatory assets – noncurrent 6,195 4,859 5,745 4,487 Deferred derivative losses 190 128 177 113 Recoverable energy costs 76 — 67 — Regulatory assets – current 266 128 244 113 Total Regulatory Assets $6,461 $4,987 $5,989 $4,600 Regulatory liabilities Future income tax* $2,207 $2,426 $2,062 $2,275 Allowance for cost of removal less salvage 1,090 989 932 843 TCJA net benefits 295 471 286 454 Net unbilled revenue deferrals 198 199 198 199 Net proceeds from sale of property 137 173 137 173 Pension and other postretirement benefit deferrals 85 75 46 46 System benefit charge carrying charge 64 48 57 44 Property tax refunds 36 45 35 45 BQDM and REV Demo reconciliations 27 27 25 26 Settlement of gas proceedings 21 10 21 10 Sales and use tax refunds 16 8 16 8 Earnings sharing - electric, gas and steam 15 22 10 15 Unrecognized other postretirement costs 11 9 — — Settlement of prudence proceeding 5 8 5 8 Workers’ compensation 3 — 3 — Energy efficiency portfolio standard unencumbered funds 1 122 — 118 Other 302 195 261 163 Regulatory liabilities – noncurrent 4,513 4,827 4,094 4,427 Refundable energy costs 28 44 4 12 Deferred derivative gains 8 34 7 34 Revenue decoupling mechanism — 24 — 17 Regulatory liabilities—current 36 102 11 63 Total Regulatory Liabilities $4,549 $4,929 $4,105 $4,490 * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.
Schedule Of Regulatory Assets Not Earning Return	Regulatory Assets Not Earning a Return Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Unrecognized and other postretirement costs $3,241 $2,541 $3,065 $2,403 Environmental remediation costs 855 727 781 647 Revenue taxes 336 296 323 285 Deferred derivative losses 120 83 111 76 Workers' compensation — 3 — 3 Other 24 21 24 20 Deferred derivative losses - current 190 128 177 112 Total 4,766 3,799 4,481 3,546

Capitalization (Tables)

Capitalization (Tables)	12 Months Ended
	Dec. 31, 2020
Debt Disclosure [Abstract]
Schedule of Long-Term Debt Maturities	Long-term debt maturing in the period 2021-2025 is as follows: (Millions of Dollars) Con Edison CECONY 2021 $1,967 $640 2022 437 — 2023 966 — 2024 385 250 2025 315 —
Carrying Amounts and Fair Values of Long-Term Debt	The carrying amounts and fair values of long-term debt at December 31, 2020 and 2019 are: (Millions of Dollars) 2020 2019 Long-Term Debt (including current portion) (a) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $22,349 $26,808 $19,973 $22,738 CECONY $16,789 $20,974 $14,964 $17,505 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020 and $178 million and $151 million for Con Edison and CECONY, respectively, as of December 31, 2019.

Pension Benefits (Tables)

Pension Benefits (Tables)	12 Months Ended
	Dec. 31, 2020
Retirement Benefits [Abstract]
Total Periodic Benefit Costs	The components of the Companies’ total periodic benefit costs for 2020, 2019 and 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 Service cost – including administrative expenses $293 $250 $290 $274 $232 $272 Interest cost on projected benefit obligation 549 601 561 515 564 525 Expected return on plan assets (1,034) (988) (1,033) (980) (936) (979) Recognition of net actuarial loss 699 518 688 661 492 651 Recognition of prior service credit (16) (17) (17) (19) (19) (19) TOTAL PERIODIC BENEFIT COST $491 $364 $489 $451 $333 $450 Cost capitalized (130) (108) (127) (123) (102) (119) Reconciliation to rate level (250) (15) (92) (239) (12) (100) Total expense recognized $111 $241 $270 $89 $219 $231 Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 Service cost $21 $18 $20 $16 $13 $14 Interest cost on accumulated other postretirement benefit obligation 37 44 42 31 36 34 Expected return on plan assets (66) (66) (73) (54) (54) (63) Recognition of net actuarial loss/(gain) 37 (9) 8 36 (10) 3 Recognition of prior service credit (3) (2) (6) (2) (2) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $26 $(15) $(9) $27 $(17) $(14) Cost capitalized (9) (7) (8) (7) (5) (6) Reconciliation to rate level (17) 12 8 (25) 7 9 Total credit recognized $— $(10) ($9) $(5) $(15) ($11)
Schedule of Funded Status	The funded status at December 31, 2020, 2019 and 2018 was as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $16,792 $14,449 $15,536 $15,750 $13,542 $14,567 Service cost – excluding administrative expenses 288 245 286 269 228 267 Interest cost on projected benefit obligation 549 601 561 515 564 525 Net actuarial loss/(gain) 2,281 2,191 (1,219) 2,154 2,076 (1,159) Plan amendments — 15 — — — — Benefits paid (945) (709) (715) (867) (660) (658) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $18,965 $16,792 $14,449 $17,821 $15,750 $13,542 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $15,608 $13,450 $14,274 $14,790 $12,744 $13,519 Actual return on plan assets 1,927 2,556 (536) 1,830 2,425 (507) Employer contributions 475 350 473 435 318 434 Benefits paid (945) (709) (715) (867) (660) (658) Administrative expenses (43) (39) (46) (41) (37) (44) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $17,022 $15,608 $13,450 $16,147 $14,790 $12,744 FUNDED STATUS $(1,943) $(1,184) $(999) $(1,674) $(960) $(798) Unrecognized net loss $3,330 $2,604 $2,464 $3,145 $2,466 $2,338 Unrecognized prior service costs/(credits) (156) (173) (205) (183) (202) (222) Accumulated benefit obligation 16,768 15,015 13,030 15,676 14,010 12,161 The funded status of the programs at December 31, 2020, 2019 and 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,357 $1,114 $1,219 $1,154 $913 $985 Service cost 21 18 20 16 13 14 Interest cost on accumulated postretirement benefit obligation 37 44 42 31 36 34 Amendments — (14) — — — — Net actuarial loss/(gain) 74 264 (70) 63 252 (32) Benefits paid and administrative expenses, net of subsidies (117) (110) (135) (107) (100) (125) Participant contributions 53 41 38 52 40 37 BENEFIT OBLIGATION AT END OF YEAR $1,425 $1,357 $1,114 $1,209 $1,154 $913 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,026 $885 $1,039 $872 $759 $893 Actual return on plan assets 142 198 (66) 117 165 (54) Employer contributions 7 7 6 4 6 6 Employer group waiver plan subsidies 20 23 34 19 22 32 Participant contributions 53 40 37 51 40 37 Benefits paid (133) (127) (165) (123) (120) (155) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $1,115 $1,026 $885 $940 $872 $759 FUNDED STATUS $(310) $(331) $(229) $(269) $(282) $(154) Unrecognized net loss/(gain) $115 $155 $14 $114 $149 $(2) Unrecognized prior service costs (16) (19) (8) (1) (3) (5)
Schedule of Assumptions	The actuarial assumptions were as follows: 2020 2019 2018 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 2.55 % 3.35 % 4.25 % Interest crediting rate for cash balance plan 3.00 % 3.30 % 4.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 4.25 % O&R 3.20 % 3.20 % 4.00 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount rate 3.35 % 4.25 % 3.70 % Interest crediting rate for cash balance plan 3.30 % 4.00 % 4.10 % Expected return on plan assets 7.00 % 7.00 % 7.50 % Rate of compensation increase CECONY 3.80 % 4.25 % 4.25 % O&R 3.20 % 4.00 % 4.00 % The actuarial assumptions were as follows: 2020 2019 2018 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 2.25 % 3.10 % 4.15 % O&R 2.55 % 3.35 % 4.30 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 3.10 % 4.15 % 3.55 % O&R 3.35 % 4.30 % 3.70 % Expected Return on Plan Assets 6.80 % 6.80 % 7.50 %
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) 2021 2022 2023 2024 2025 2026-2030 Con Edison $764 $776 $793 $807 $821 $4,295 CECONY 706 718 733 747 760 3,992 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) 2021 2022 2023 2024 2025 2026-2030 Con Edison $84 $84 $84 $84 $84 $409 CECONY 76 75 75 75 75 358
Schedule of Plan Assets Allocations	The asset allocations for the pension plan at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2021 2020 2019 2018 Equity Securities 45% - 55% 51 % 51 % 51 % Debt Securities 33% - 43% 38 % 38 % 39 % Real Estate 10% - 14% 11 % 11 % 10 % Total 100% 100 % 100 % 100 % The asset allocations for CECONY’s other postretirement benefit plans at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2021 2020 2019 2018 Equity Securities 42%-80% 54 % 54 % 52 % Debt Securities 20%-58% 46 % 46 % 48 % Total 100% 100 % 100 % 100 %
Schedule of Fair Value of Plan Assets	The fair values of the pension plan assets at December 31, 2020 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,202 $— $4,202 International Equity (b) 3,693 — 3,693 U.S. Government Issued Debt (c) — 1,424 1,424 Corporate Bonds Debt (d) — 3,535 3,535 Structured Assets Debt (e) — 188 188 Other Fixed Income Debt (f) — 1,067 1,067 Cash and Cash Equivalents (g) 51 408 459 Total investments within the fair value hierarchy $7,946 $6,622 $14,568 Investments measured at NAV per share (m) Private Equity (h) 635 Real Estate (i) 1,880 Hedge Funds (j) 292 Total investments valued using NAV per share $2,807 Funds for retiree health benefits (k) (116) (97) (213) Funds for retiree health benefits measured at NAV per share (k)(m) (41) Total funds for retiree health benefits $(254) Investments (excluding funds for retiree health benefits) $7,830 $6,525 $17,121 Pending activities (l) (99) Total fair value of plan net assets $17,022 (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) Private Equity consists of global equity funds that are not exchange-traded. (i) Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type. (j) Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments. (k) 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. (l) 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. (m) 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, 2019 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $3,652 $— $3,652 International Equity (b) 3,354 — 3,354 U.S. Government Issued Debt (c) — 1,496 1,496 Corporate Bonds Debt (d) — 3,260 3,260 Structured Assets Debt (e) — 173 173 Other Fixed Income Debt (f) — 955 955 Cash and Cash Equivalents (g) — 326 326 Total investments within the fair value hierarchy $7,006 $6,210 $13,216 Investments measured at NAV per share (m) Private Equity (h) 555 Real Estate (i) 1,806 Hedge Funds (j) 270 Total investments valued using NAV per share $2,631 Funds for retiree health benefits (k) (110) (98) (208) Funds for retiree health benefits measured at NAV per share (k)(m) (42) Total funds for retiree health benefits $(250) Investments (excluding funds for retiree health benefits) $6,896 $6,112 $15,597 Pending activities (l) 11 Total fair value of plan net assets $15,608 (a) - (m) Reference is made to footnotes (a) through (m) in the above table of pension plan assets at December 31, 2020 by asset category. The fair values of the plans' assets at December 31, 2020 by asset category as defined by the accounting rules for fair value measurements (see Note Q) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $448 $448 Other Fixed Income Debt (b) — 367 367 Cash and Cash Equivalents (c) — 27 27 Total investments $— $842 $842 Funds for retiree health benefits (d) 116 97 213 Investments (including funds for retiree health benefits) $116 $939 $1,055 Funds for retiree health benefits measured at net asset value (d)(e) 41 Pending activities (f) 19 Total fair value of plan net assets $1,115 (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, 2019 by asset category (see Note Q) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $404 $404 Other Fixed Income Debt (b) — 331 331 Cash and Cash Equivalents (c) — 23 23 Total investments $— $758 $758 Funds for retiree health benefits (d) 110 98 208 Investments (including funds for retiree health benefits) $110 $856 $966 Funds for retiree health benefits measured at net asset value (d)(e) 42 Pending activities (f) 18 Total fair value of plan net assets $1,026
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) 2020 2019 2018 Con Edison $52 $49 $45 CECONY 43 42 39

Other Postretirement Benefits (

Other Postretirement Benefits (Tables)	12 Months Ended
	Dec. 31, 2020
Retirement Benefits [Abstract]
Net Periodic Benefit Costs	The components of the Companies’ total periodic benefit costs for 2020, 2019 and 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 Service cost – including administrative expenses $293 $250 $290 $274 $232 $272 Interest cost on projected benefit obligation 549 601 561 515 564 525 Expected return on plan assets (1,034) (988) (1,033) (980) (936) (979) Recognition of net actuarial loss 699 518 688 661 492 651 Recognition of prior service credit (16) (17) (17) (19) (19) (19) TOTAL PERIODIC BENEFIT COST $491 $364 $489 $451 $333 $450 Cost capitalized (130) (108) (127) (123) (102) (119) Reconciliation to rate level (250) (15) (92) (239) (12) (100) Total expense recognized $111 $241 $270 $89 $219 $231 Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 Service cost $21 $18 $20 $16 $13 $14 Interest cost on accumulated other postretirement benefit obligation 37 44 42 31 36 34 Expected return on plan assets (66) (66) (73) (54) (54) (63) Recognition of net actuarial loss/(gain) 37 (9) 8 36 (10) 3 Recognition of prior service credit (3) (2) (6) (2) (2) (2) TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT) $26 $(15) $(9) $27 $(17) $(14) Cost capitalized (9) (7) (8) (7) (5) (6) Reconciliation to rate level (17) 12 8 (25) 7 9 Total credit recognized $— $(10) ($9) $(5) $(15) ($11)
Schedule of Funded Status	The funded status at December 31, 2020, 2019 and 2018 was as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Projected benefit obligation at beginning of year $16,792 $14,449 $15,536 $15,750 $13,542 $14,567 Service cost – excluding administrative expenses 288 245 286 269 228 267 Interest cost on projected benefit obligation 549 601 561 515 564 525 Net actuarial loss/(gain) 2,281 2,191 (1,219) 2,154 2,076 (1,159) Plan amendments — 15 — — — — Benefits paid (945) (709) (715) (867) (660) (658) PROJECTED BENEFIT OBLIGATION AT END OF YEAR $18,965 $16,792 $14,449 $17,821 $15,750 $13,542 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $15,608 $13,450 $14,274 $14,790 $12,744 $13,519 Actual return on plan assets 1,927 2,556 (536) 1,830 2,425 (507) Employer contributions 475 350 473 435 318 434 Benefits paid (945) (709) (715) (867) (660) (658) Administrative expenses (43) (39) (46) (41) (37) (44) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $17,022 $15,608 $13,450 $16,147 $14,790 $12,744 FUNDED STATUS $(1,943) $(1,184) $(999) $(1,674) $(960) $(798) Unrecognized net loss $3,330 $2,604 $2,464 $3,145 $2,466 $2,338 Unrecognized prior service costs/(credits) (156) (173) (205) (183) (202) (222) Accumulated benefit obligation 16,768 15,015 13,030 15,676 14,010 12,161 The funded status of the programs at December 31, 2020, 2019 and 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 CHANGE IN BENEFIT OBLIGATION Benefit obligation at beginning of year $1,357 $1,114 $1,219 $1,154 $913 $985 Service cost 21 18 20 16 13 14 Interest cost on accumulated postretirement benefit obligation 37 44 42 31 36 34 Amendments — (14) — — — — Net actuarial loss/(gain) 74 264 (70) 63 252 (32) Benefits paid and administrative expenses, net of subsidies (117) (110) (135) (107) (100) (125) Participant contributions 53 41 38 52 40 37 BENEFIT OBLIGATION AT END OF YEAR $1,425 $1,357 $1,114 $1,209 $1,154 $913 CHANGE IN PLAN ASSETS Fair value of plan assets at beginning of year $1,026 $885 $1,039 $872 $759 $893 Actual return on plan assets 142 198 (66) 117 165 (54) Employer contributions 7 7 6 4 6 6 Employer group waiver plan subsidies 20 23 34 19 22 32 Participant contributions 53 40 37 51 40 37 Benefits paid (133) (127) (165) (123) (120) (155) FAIR VALUE OF PLAN ASSETS AT END OF YEAR $1,115 $1,026 $885 $940 $872 $759 FUNDED STATUS $(310) $(331) $(229) $(269) $(282) $(154) Unrecognized net loss/(gain) $115 $155 $14 $114 $149 $(2) Unrecognized prior service costs (16) (19) (8) (1) (3) (5)
Schedule of Actuarial Assumptions	The actuarial assumptions were as follows: 2020 2019 2018 Weighted-average assumptions used to determine benefit obligations at December 31: Discount rate 2.55 % 3.35 % 4.25 % Interest crediting rate for cash balance plan 3.00 % 3.30 % 4.00 % Rate of compensation increase CECONY 3.80 % 3.80 % 4.25 % O&R 3.20 % 3.20 % 4.00 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount rate 3.35 % 4.25 % 3.70 % Interest crediting rate for cash balance plan 3.30 % 4.00 % 4.10 % Expected return on plan assets 7.00 % 7.00 % 7.50 % Rate of compensation increase CECONY 3.80 % 4.25 % 4.25 % O&R 3.20 % 4.00 % 4.00 % The actuarial assumptions were as follows: 2020 2019 2018 Weighted-average assumptions used to determine benefit obligations at December 31: Discount Rate CECONY 2.25 % 3.10 % 4.15 % O&R 2.55 % 3.35 % 4.30 % Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31: Discount Rate CECONY 3.10 % 4.15 % 3.55 % O&R 3.35 % 4.30 % 3.70 % Expected Return on Plan Assets 6.80 % 6.80 % 7.50 %
Schedule of Change of Assumed Health Care Cost Trend Rate
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) 2021 2022 2023 2024 2025 2026-2030 Con Edison $764 $776 $793 $807 $821 $4,295 CECONY 706 718 733 747 760 3,992 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) 2021 2022 2023 2024 2025 2026-2030 Con Edison $84 $84 $84 $84 $84 $409 CECONY 76 75 75 75 75 358
Schedule of Plan Assets Allocations	The asset allocations for the pension plan at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2021 2020 2019 2018 Equity Securities 45% - 55% 51 % 51 % 51 % Debt Securities 33% - 43% 38 % 38 % 39 % Real Estate 10% - 14% 11 % 11 % 10 % Total 100% 100 % 100 % 100 % The asset allocations for CECONY’s other postretirement benefit plans at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows: Target Allocation Range Plan Assets at December 31, Asset Category 2021 2020 2019 2018 Equity Securities 42%-80% 54 % 54 % 52 % Debt Securities 20%-58% 46 % 46 % 48 % Total 100% 100 % 100 % 100 %
Schedule of Fair Value of Plan Assets	The fair values of the pension plan assets at December 31, 2020 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $4,202 $— $4,202 International Equity (b) 3,693 — 3,693 U.S. Government Issued Debt (c) — 1,424 1,424 Corporate Bonds Debt (d) — 3,535 3,535 Structured Assets Debt (e) — 188 188 Other Fixed Income Debt (f) — 1,067 1,067 Cash and Cash Equivalents (g) 51 408 459 Total investments within the fair value hierarchy $7,946 $6,622 $14,568 Investments measured at NAV per share (m) Private Equity (h) 635 Real Estate (i) 1,880 Hedge Funds (j) 292 Total investments valued using NAV per share $2,807 Funds for retiree health benefits (k) (116) (97) (213) Funds for retiree health benefits measured at NAV per share (k)(m) (41) Total funds for retiree health benefits $(254) Investments (excluding funds for retiree health benefits) $7,830 $6,525 $17,121 Pending activities (l) (99) Total fair value of plan net assets $17,022 (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) Private Equity consists of global equity funds that are not exchange-traded. (i) Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type. (j) Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments. (k) 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. (l) 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. (m) 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, 2019 by asset category are as follows: (Millions of Dollars) Level 1 Level 2 Total Investments within the fair value hierarchy U.S. Equity (a) $3,652 $— $3,652 International Equity (b) 3,354 — 3,354 U.S. Government Issued Debt (c) — 1,496 1,496 Corporate Bonds Debt (d) — 3,260 3,260 Structured Assets Debt (e) — 173 173 Other Fixed Income Debt (f) — 955 955 Cash and Cash Equivalents (g) — 326 326 Total investments within the fair value hierarchy $7,006 $6,210 $13,216 Investments measured at NAV per share (m) Private Equity (h) 555 Real Estate (i) 1,806 Hedge Funds (j) 270 Total investments valued using NAV per share $2,631 Funds for retiree health benefits (k) (110) (98) (208) Funds for retiree health benefits measured at NAV per share (k)(m) (42) Total funds for retiree health benefits $(250) Investments (excluding funds for retiree health benefits) $6,896 $6,112 $15,597 Pending activities (l) 11 Total fair value of plan net assets $15,608 (a) - (m) Reference is made to footnotes (a) through (m) in the above table of pension plan assets at December 31, 2020 by asset category. The fair values of the plans' assets at December 31, 2020 by asset category as defined by the accounting rules for fair value measurements (see Note Q) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $448 $448 Other Fixed Income Debt (b) — 367 367 Cash and Cash Equivalents (c) — 27 27 Total investments $— $842 $842 Funds for retiree health benefits (d) 116 97 213 Investments (including funds for retiree health benefits) $116 $939 $1,055 Funds for retiree health benefits measured at net asset value (d)(e) 41 Pending activities (f) 19 Total fair value of plan net assets $1,115 (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, 2019 by asset category (see Note Q) are as follows: (Millions of Dollars) Level 1 Level 2 Total Equity (a) $— $404 $404 Other Fixed Income Debt (b) — 331 331 Cash and Cash Equivalents (c) — 23 23 Total investments $— $758 $758 Funds for retiree health benefits (d) 110 98 208 Investments (including funds for retiree health benefits) $110 $856 $966 Funds for retiree health benefits measured at net asset value (d)(e) 42 Pending activities (f) 18 Total fair value of plan net assets $1,026

Environmental Matters (Tables)

Environmental Matters (Tables)	12 Months Ended
	Dec. 31, 2020
Environmental Remediation Obligations [Abstract]
Accrued Liabilities and Regulatory Assets	The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Accrued Liabilities: Manufactured gas plant sites $752 $640 $676 $561 Other Superfund Sites 105 94 104 93 Total $857 $734 $780 $654 Regulatory assets $865 $732 $791 $647
Environmental Remediation Costs	Environmental remediation costs incurred related to Superfund Sites at December 31, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Remediation costs incurred $33 $19 $32 $13
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 for the Companies at December 31, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $72 $78 $68 $73 Regulatory assets/(liabilities) – workers’ compensation $(3) $3 $(3) $3

Material Contingencies (Tables)

Material Contingencies (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) Con Edison Transmission $393 $177 $— $570 Energy transactions 480 51 222 753 Renewable electric production projects 285 9 355 649 Other 70 — — 70 Total $1,228 $237 $577 $2,042

Electricity Purchase Agreemen_2

Electricity Purchase Agreements (Tables)	12 Months Ended
	Dec. 31, 2020
Regulated Operations [Abstract]
Summary of Estimated Capacity and Other Fixed Payments	The future capacity and other fixed payments under the electricity purchase agreements are estimated to be as follows: (Millions of Dollars) 2021 2022 2023 2024 2025 All Years Thereafter Con Edison $141 $106 $68 $53 $54 $487 CECONY 138 106 68 53 54 487
Summary of Capacity, Energy and Other Fixed Payments	The company’s payments under the significant terms of the agreements for capacity, energy and other fixed payments in 2020, 2019 and 2018 were as follows: For the Years Ended December 31, (Millions of Dollars) 2020 2019 2018 Indian Point (a) $— $— $6 Astoria Generating Company (b) 26 116 179 Brooklyn Navy Yard (c) 113 115 124 Cogen Technologies — — 9 Total $139 $231 $318 (a) Contract term ended in 2018. (b) Capacity purchase agreements with terms ending in 2020 and 2023. (c) Contract for plant output, which started in 1996 and ends in 2036.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 and 2019 were as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Operating lease cost $85 $83 $65 $64 Operating lease cash flows $79 $75 $61 $60 Con Edison CECONY 2020 2019 2020 2019 Weighted Average Remaining Lease Term: Operating leases 19.1 years 19.8 years 13.0 years 14.0 years Finance leases 7.3 years 12.2 years 4.0 years 2.4 years Weighted Average Discount Rate: Operating leases 4.3% 4.3% 3.6% 3.6% Finance leases 1.8% 3.5% 1.3% 4.1%
Operating Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, Operating Leases Finance Leases Operating Leases Finance Leases 2021 $79 $1 $62 $1 2022 77 1 58 1 2023 74 — 57 — 2024 75 — 57 — 2025 75 — 58 — All years thereafter 938 1 451 — Total future minimum lease payments $1,318 $3 $743 $2 Less: imputed interest (458) — (158) — Total $860 $3 $585 $2 Reported as of December 31, 2020 Operating lease liabilities (current) $96 $— $73 $— Operating lease liabilities (noncurrent) 764 — 512 — Other current liabilities — 1 — 1 Other noncurrent liabilities — 2 — 1 Total $860 $3 $585 $2
Finance Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending December 31, Operating Leases Finance Leases Operating Leases Finance Leases 2021 $79 $1 $62 $1 2022 77 1 58 1 2023 74 — 57 — 2024 75 — 57 — 2025 75 — 58 — All years thereafter 938 1 451 — Total future minimum lease payments $1,318 $3 $743 $2 Less: imputed interest (458) — (158) — Total $860 $3 $585 $2 Reported as of December 31, 2020 Operating lease liabilities (current) $96 $— $73 $— Operating lease liabilities (noncurrent) 764 — 512 — Other current liabilities — 1 — 1 Other noncurrent liabilities — 2 — 1 Total $860 $3 $585 $2

Income Tax (Tables)

Income Tax (Tables)	12 Months Ended
	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax	The components of income tax are as follows: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 State Current $7 $(12) $(10) $6 $22 $6 Deferred 50 96 107 97 68 82 Federal Current (2) — 3 41 185 (34) Deferred 42 219 310 73 63 275 Amortization of investment tax credits (7) (7) (9) (2) (3) (3) Total income tax expense $90 $296 $401 $215 $335 $326
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) 2020 2019 2020 2019 Deferred tax liabilities: Property basis differences $7,985 $7,699 $6,901 $6,640 Regulatory assets: Unrecognized pension and other postretirement costs 910 712 861 674 Environmental remediation costs 243 205 222 181 Deferred storm costs 31 22 — — Other regulatory assets 536 376 508 355 Operating lease right-of-use asset 220 231 165 169 Equity investments 46 104 — — Total deferred tax liabilities $9,971 $9,349 $8,657 $8,019 Deferred tax assets: Accrued pension and other postretirement costs $504 $291 $427 $222 Regulatory liabilities: Future income tax 617 678 579 638 Other regulatory liabilities 656 702 570 622 Superfund and other environmental costs 241 206 219 183 Asset retirement obligations 178 135 143 102 Operating lease liabilities 211 231 165 170 Loss carryforwards 164 108 34 — Tax credits carryforward 1,022 896 — — Valuation allowance (22) (31) — — Other 59 47 127 103 Total deferred tax assets 3,630 3,263 2,264 2,040 Net deferred tax liabilities $6,341 $6,086 $6,393 $5,979 Unamortized investment tax credits 134 141 18 21 Net deferred tax liabilities and unamortized investment tax credits $6,475 $6,227 $6,411 $6,000
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) 2020 2019 2018 2020 2019 2018 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 4 4 4 5 5 5 Taxes attributable to noncontrolling interests (1) (1) — — — — Cost of removal 2 1 1 1 1 1 Other plant-related items (1) (1) (1) (1) (1) (1) TCJA deferred tax re-measurement — — 2 — — — Amortization of excess deferred federal income taxes (14) (4) (3) (12) (4) (3) Renewable energy credits (3) (2) (1) — — — Research and development credits — (1) — — (1) (1) Other (1) — — 1 — (1) Effective tax rate 7 % 17 % 23 % 15 % 21 % 21 %
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) 2020 2019 2018 2020 2019 2018 Balance at January 1, $13 $6 $12 $2 $4 $5 Additions based on tax positions related to the current year — 1 2 — 1 2 Additions based on tax positions of prior years 1 10 1 1 — 1 Reductions for tax positions of prior years — (2) (2) — (1) (1) Reductions from expiration of statute of limitations — — (4) — — — Settlements — (2) (3) — (2) (3) Balance at December 31, $14 $13 $6 $3 $2 $4

Revenue Recognition (Tables)

Revenue Recognition (Tables)	12 Months Ended
	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table presents, for the years ended December 31, 2020 and 2019, 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. 2020 2019 2018 (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 $8,026 $77 $8,103 $7,913 $149 $8,062 $7,920 $51 $7,971 Gas 1,998 38 2,036 2,097 35 2,132 2,052 26 2,078 Steam 494 14 508 610 17 627 625 6 631 Total CECONY $10,518 $129 $10,647 $10,620 $201 $10,821 $10,597 $83 $10,680 O&R Electric 619 10 629 627 7 634 647 (5) 642 Gas 224 9 233 247 12 259 256 (7) 249 Total O&R $843 $19 $862 $874 $19 $893 $903 $(12) $891 Clean Energy Businesses Renewables 609 (b) — 609 575 (b) — 575 329 (b) — 329 Energy services 52 — 52 71 — 71 95 — 95 Other — 75 75 — 211 211 — 339 339 Total Clean Energy Businesses $661 $75 $736 $646 $211 $857 $424 $339 $763 Con Edison Transmission 4 — 4 4 — 4 4 — 4 Other (c) — (3) (3) — (1) (1) — (1) (1) Total Con Edison $12,026 $220 $12,246 $12,144 $430 $12,574 $11,928 $409 $12,337 (a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans. For the Clean Energy Businesses, this includes revenue from wholesale services. (b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $8 million, $14 million and $103 million for the years ended December 31, 2020, 2019 and 2018, respectively, of revenue related to engineering, procurement and construction services. (c) Parent company and consolidation adjustments.
Change in Unbilled Contract and Unearned Revenues	2020 2019 2018 (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, $29 $17 $29 $20 $58 $87 Additions (c) 88 31 86 1 144 38 Subtractions (c) 106 7 (d) 86 4 (d) 173 105 (d) Ending balance as of December 31, $11 $41 $29 $17 $29 $20 (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, $7 million, $4 million and $50 million were included in the balances as of January 1, 2020, 2019, and 2018, respectively.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020, 2019 and 2018: Con Edison CECONY (Millions of Dollars) 2020 2019 2018 2020 2019 2018 Performance-based restricted stock $7 $36 $3 $6 $30 $3 Time-based restricted stock 1 2 2 1 2 1 Non-employee director deferred stock compensation 2 2 3 2 2 3 Stock purchase plan 7 7 6 7 6 6 Total $17 $47 $14 $16 $40 $13 Income tax benefit $5 $13 $4 $4 $11 $4
Assumptions Used to Calculate Fair Value of Awards	The assumptions used to calculate the fair value of the awards were as follows: 2020 2019 2018 Risk-free interest rate (a) 0.10% - 0.13% 1.58% - 1.59% 2.48% -2.63% Expected term (b) 3 years 3 years 3 years Expected share price volatility (c) 30.16% - 40.95% 12.89% - 15.51% 14.76% - 17.71% (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.
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, 2020 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, 2019 991,238 $68.15 $77.14 742,204 $68.06 $77.32 Granted 329,600 79.98 90.48 249,761 79.70 89.65 Vested (326,496) 73.07 74.57 (245,269) 72.70 74.76 Forfeited (92,818) 73.80 87.98 (60,225) 73.61 87.73 Non-vested at December 31, 2020 901,524 $70.11 $81.83 686,471 $70.15 $81.80 (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, 2020 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, 2019 67,250 $80.36 63,100 $80.36 Granted 22,450 78.00 20,900 78.00 Vested (20,750) 77.66 (19,650) 77.66 Forfeited (1,512) 80.30 (1,512) 80.30 Non-vested at December 31, 2020 67,438 $80.40 62,838 $80.42

Financial Information by Busi_2

Financial Information by Business Segment (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 (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 $8,103 $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 $616 Con Edison Transmission 4 — 1 (8) (215) 18 — 1,348 3 Other (b) (3) — — (10) (5) 25 (3) 485 — Total Con Edison $12,246 $— $1,920 $2,654 $(401) $1,019 $193 $62,895 $4,085 As of and for the Year Ended December 31, 2019 (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 $8,062 $17 $1,053 $1,758 $(28) $539 $239 $32,988 $1,851 Gas 2,132 7 231 528 (4) 147 99 11,090 1,078 Steam 627 70 89 62 (3) 42 4 2,479 91 Consolidation adjustments — (94) — — — — — — — Total CECONY $10,821 $— $1,373 $2,348 $(35) $728 $342 $46,557 $3,020 O&R Electric $634 $— $60 $98 $(7) $27 $15 $2,130 $142 Gas 259 — 24 41 (4) 14 6 876 61 Other — — — — — — — — — Total O&R $893 $— $84 $139 $(11) $41 $21 $3,006 $203 Clean Energy Businesses $857 $— $226 $202 $5 $186 $(58) $6,528 $248 Con Edison Transmission 4 — 1 (6) 104 25 1 1,618 205 Other (b) (1) — — (7) (12) 11 (6) 370 — Total Con Edison $12,574 $— $1,684 $2,676 $51 $991 $300 $58,079 $3,676 As of and for the Year Ended December 31, 2018 (Millions of Dollars) Operating Inter- Depreciation Operating Other Income (deductions) Interest Income Total Capital CECONY Electric $7,971 $16 $984 $1,799 $(110) $519 $233 $31,012 $1,861 Gas 2,078 7 205 478 (23) 131 87 9,710 1,050 Steam 631 75 87 77 (10) 39 8 2,386 94 Consolidation adjustments — (98) — — — — — — — Total CECONY $10,680 $— $1,276 $2,354 $(143) $689 $328 $43,108 $3,005 O&R Electric $642 $— $56 $93 $(14) $25 $14 $2,036 $138 Gas 249 — 21 39 (5) 14 7 856 67 Other — — — — — — — — — Total O&R $891 $— $77 $132 $(19) $39 $21 $2,892 $205 Clean Energy Businesses $763 $— $85 $194 $33 $63 $19 $5,821 $1,791 Con Edison Transmission 4 — 1 (7) 91 20 (1) 1,425 248 Other (b) (1) — (1) (9) (24) 8 39 674 — Total Con Edison $12,337 $— $1,438 $2,664 $(62) $819 $406 $53,920 $5,249 (a) For Con Edison, the income tax expense/(benefit) on non-operating income was $(103) million, $(4) million and $(5) million in 2020, 2019 and 2018, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(3) million, $(7) million and $(2) million in 2020, 2019 and 2018, respectively. (b) 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, 2020
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, 2020 and 2019 were: (Millions of Dollars) 2020 2019 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 $44 $14 $58 (b) $60 $(3) $57 (b) Noncurrent 22 35 57 19 (13) 6 (d) Total fair value of derivative assets $66 $49 $115 $79 $(16) $63 Fair value of derivative liabilities Current $(225) $(13) $(238) (c) $(140) $17 $(123) (d) Noncurrent (207) (33) (240) (c) (122) 16 (106) (d) Total fair value of derivative liabilities $(432) $(46) $(478) $(262) $33 $(229) Net fair value derivative assets/(liabilities) $(366) $3 $(363) $(183) $17 $(166) CECONY Fair value of derivative assets Current $20 $(12) $8 (b) $39 $(6) $33 (b) Noncurrent 16 (8) 8 17 (12) 5 Total fair value of derivative assets $36 $(20) $16 $56 $(18) $38 Fair value of derivative liabilities Current $(174) $11 $(163) $(100) $19 $(81) Noncurrent (114) 9 (105) (80) 16 (64) Total fair value of derivative liabilities $(288) $20 $(268) $(180) $35 $(145) Net fair value derivative assets/(liabilities) $(252) $— $(252) $(124) $17 $(107) (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, 2020 and 2019, margin deposits for Con Edison ($3 million and $9 million, respectively) and CECONY ($3 million and $8 million, 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 $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps range from 2024-2041. (d) Includes amounts for interest rate swaps of $1 million in current assets, $(7) million in current liabilities and $(34) million in noncurrent liabilities. At December 31, 2019, the Clean Energy Businesses had interest rate swaps with notional amounts of $919 million. The expiration dates of the swaps range from 2024-2041.
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, 2020 and 2019 were: (Millions of Dollars) 2020 2019 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 $44 $14 $58 (b) $60 $(3) $57 (b) Noncurrent 22 35 57 19 (13) 6 (d) Total fair value of derivative assets $66 $49 $115 $79 $(16) $63 Fair value of derivative liabilities Current $(225) $(13) $(238) (c) $(140) $17 $(123) (d) Noncurrent (207) (33) (240) (c) (122) 16 (106) (d) Total fair value of derivative liabilities $(432) $(46) $(478) $(262) $33 $(229) Net fair value derivative assets/(liabilities) $(366) $3 $(363) $(183) $17 $(166) CECONY Fair value of derivative assets Current $20 $(12) $8 (b) $39 $(6) $33 (b) Noncurrent 16 (8) 8 17 (12) 5 Total fair value of derivative assets $36 $(20) $16 $56 $(18) $38 Fair value of derivative liabilities Current $(174) $11 $(163) $(100) $19 $(81) Noncurrent (114) 9 (105) (80) 16 (64) Total fair value of derivative liabilities $(288) $20 $(268) $(180) $35 $(145) Net fair value derivative assets/(liabilities) $(252) $— $(252) $(124) $17 $(107) (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, 2020 and 2019, margin deposits for Con Edison ($3 million and $9 million, respectively) and CECONY ($3 million and $8 million, 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 $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps range from 2024-2041. (d) Includes amounts for interest rate swaps of $1 million in current assets, $(7) million in current liabilities and $(34) million in noncurrent liabilities. At December 31, 2019, the Clean Energy Businesses had interest rate swaps with notional amounts of $919 million. The expiration dates of the swaps range from 2024-2041.
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, 2020 and 2019: Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2020 2019 2020 2019 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $(26) $4 $(27) $5 Noncurrent Deferred derivative gains — (3) — (1) Total deferred gains/(losses) $(26) $1 $(27) $4 Current Deferred derivative losses $(63) $(91) $(64) $(83) Current Recoverable energy costs (201) (142) (177) (124) Noncurrent Deferred derivative losses (37) (67) (36) (65) Total deferred gains/(losses) $(301) $(300) $(277) $(272) Net deferred gains/(losses) $(327) $(299) $(304) $(268) Income Statement Location Pre-tax gain/(loss) recognized in income Gas purchased for resale $(2) $(2) $— $— Non-utility revenue 7 25 — — Other operations and maintenance expense (3) 1 (3) 1 Other interest expense (65) (36) — — Total pre-tax gain/(loss) recognized in income $(63) $(12) $(3) $1
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, 2020: Electric Energy (MWh) (a)(b) Capacity (MW) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 28,102,230 47,258 286,819,910 7,728,000 CECONY 26,193,800 35,400 267,380,000 7,728,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes.
Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features	The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at December 31, 2020: (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $293 $277 Collateral posted 212 200 Additional collateral (b) (downgrade one level from current ratings) 5 — Additional collateral (b)(c) (downgrade to below investment grade from current ratings) 101 85 (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 $25 million at December 31, 2020. 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, 2020, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $51 million.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 and 2019 are summarized below. 2020 2019 (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) $19 $42 $4 $53 $118 $4 $61 $2 $4 $71 Interest rate swaps (a)(b)(c)(f) — — — — — — 1 — — 1 Other (a)(b)(d) 431 126 — — 557 353 125 — — 478 Total assets $450 $168 $4 $53 $675 $357 $187 $2 $4 $550 Derivative liabilities: Commodity (a)(b)(c) $7 $296 $23 $46 $372 $18 $174 $18 $(22) $188 Interest rate swaps (a)(b)(c)(f) — 106 — — 106 — 41 — — 41 Total liabilities $7 $402 $23 $46 $478 $18 $215 $18 $(22) $229 CECONY Derivative assets: Commodity (a)(b)(c) $15 $20 $— $(16) $19 $3 $42 $1 $— $46 Other (a)(b)(d) 411 120 — — 531 333 119 — — 452 Total assets $426 $140 $— $(16) $550 $336 $161 $1 $— $498 Derivative liabilities: Commodity (a)(b)(c) $3 $274 $10 $(19) $268 $15 $147 $7 $(24) $145 (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 $1 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2020 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, 2020 to less than three years as of December 31, 2020. Con Edison and CECONY had $24 million and $22 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2019 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of December 31, 2017 to less than three years as of December 31, 2019. (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, 2020 and 2019, 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 P.
Schedule of Commodity Derivatives	Fair Value of Level 3 at December 31, 2020 (Millions of Dollars) Valuation Techniques Unobservable Inputs Range Con Edison — Commodity Electricity (20) Discounted Cash Flow Forward capacity prices (a) $0.06-$6.26 per kW-month Transmission Congestion Contracts/Financial Transmission Rights 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $(2.65)-$7.69 per MWh Total Con Edison — Commodity $(19) CECONY — Commodity Electricity $(11) Discounted Cash Flow Forward capacity prices (a) $0.08-$6.26 per kW-month Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.23-$1.13 per MWh Total CECONY — Commodity $(10) (a) Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement. (b) Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement.
Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value	The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the years ended December 31, 2020 and 2019 and classified as Level 3 in the fair value hierarchy: Con Edison CECONY (Millions of Dollars) 2020 2019 2020 2019 Beginning balance as of January 1, $(16) $(13) $(6) $(2) Included in earnings (10) (5) (5) — Included in regulatory assets and liabilities (7) 18 (4) 17 Settlements 15 8 6 1 Transfer out of level 3 (1) (24) (1) (22) Ending balance as of December 31, $(19) $(16) $(10) $(6)

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2020
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Business Acquisitions, by Acquisition	At December 31, 2020 and 2019, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs: Tax Equity Projects Great Valley Solar Copper Mountain - Mesquite Solar (Millions of Dollars) 2020 2019 2020 2019 Non-utility property, less accumulated depreciation (f)(g) 284 293 446 461 Other assets 39 40 176 128 Total assets (a) $323 $333 $622 $589 Other liabilities 13 17 71 18 Total liabilities (b) $13 $17 $71 $18 (a) The assets of the Tax Equity Projects represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE. (b) The liabilities of the Tax Equity Projects represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. (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 $82 million and $62 million at December 31, 2020 and 2019, 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 $134 million and $126 million at December 31, 2020 and 2019, respectively. (f) Non-utility property is reduced by accumulated depreciation of $18 million for Great Valley Solar and $30 million for Copper Mountain - Mesquite Solar at December 31, 2020. (g) Non-utility property is reduced by accumulated depreciation of $9 million for Great Valley Solar, $15 million for Copper Mountain - Mesquite Solar at December 31, 2019.
Summary of VIEs	The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2020: 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 California $228 Copper Mountain - Mesquite Solar (c) 344 20-25 2018 Nevada and Arizona 417 (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 and Copper Mountain Mesquite Solar, refer to (d) and (e) in the table above.

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020, 2019 and 2018 were as follows: CECONY (Millions of Dollars) 2020 2019 2018 Cost of services provided $128 $121 $115 Cost of services received 66 64 73

Acquisitions, Investments and_2

Acquisitions, Investments and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2020
Business Combinations [Abstract]
Pro Forma Supplemental Information	Con Edison's revenues and net income for the years ended December 31, 2018 and 2017 as reported and pro forma to account on a consolidated basis for the acquisition as if the acquisition had been completed on January 1, 2017 instead of December 13, 2018 are as follows: Years ended December 31, (Millions of Dollars) 2018 2017 As Reported Revenue $12,337 $12,033 Net income 1,382 1,525 PRO FORMA SUPPLEMENTAL INFORMATION If Acquired January 1, 2017 (a)(b) Revenue $12,655 $12,331 Net income 1,279 1,612 (a) Reflects the following material adjustments: • included additional interest expense of $37 million and $38 million in 2018 and 2017, respectively, that would have been incurred if $825 million that was borrowed in December 2018 under a variable rate term loan agreement to fund a portion of the purchase price for the acquisition had instead been borrowed for such purpose on January 1, 2017 at a fixed rate of 4.64% per annum; and • with respect to the Previously-Owned JV Interests: eliminated the $131 million purchase accounting gain (pre-tax) that Con Edison recognized upon the completion of the acquisition in 2018 and reflected the $131 million purchase accounting gain in 2017; recorded the corresponding increase to the book value of the related net utility plant and power purchase agreement intangible asset as of January 1, 2017 instead of December 13, 2018, and included the increased depreciation and amortization expense in 2018 and 2017; and eliminated $33 million and $32 million of other income that Con Edison had recorded in 2018 and 2017, respectively, under the equity method of accounting. (b) Recalculating each investor’s claim on the investee’s assets under the contractual liquidation waterfall as if the acquisition had been completed on January 1, 2017 is impracticable. Accordingly, no HLBV adjustments were made.

General (Details)

General (Details)	12 Months Ended
	Dec. 31, 2020registrantsubsidiary
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 - Adoption of New Standard (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	$ 78
Accounts receivable - customers
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	70
Recoveries	8
Write-offs	(54)
Reserve adjustments	124
Ending Balance	148
Other receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	4
Recoveries	0
Write-offs	(2)
Reserve adjustments	5
Ending Balance	7
CECONY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	73
CECONY | Accounts receivable - customers
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	65
Recoveries	6
Write-offs	(50)
Reserve adjustments	117
Ending Balance	138
CECONY | Other receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	3
Recoveries	0
Write-offs	(1)
Reserve adjustments	2
Ending Balance	$ 4

Summary of Significant Accoun_5

Summary of Significant Accounting Policies and Other Matters - Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Revenue from External Customer [Line Items]
Excise taxes	$ 335	$ 323	$ 330
CECONY
Revenue from External Customer [Line Items]
Excise taxes	$ 323	$ 312	$ 318

Summary of Significant Accoun_6

Summary of Significant Accounting Policies and Other Matters - Plant and Depreciation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Public Utility, Property, Plant and Equipment [Line Items]
Accumulated amortization	$ 228	$ 126
Annual aggregate depreciation allowance	1,694
Other deferred charges and noncurrent assets	54
Prepaid Expense	12
Depreciation expense, other deferred charges and noncurrent assets and prepayments	7
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	10
Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	86	93
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 17	$ 10
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 | Wind Power Generating Assets
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	30 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%	5.10%	5.40%
Average depreciation rates (percent)	3.50%	3.20%	3.20%
Annual aggregate depreciation allowance	$ 1,604
Other deferred charges and noncurrent assets	51
Prepaid Expense	11
Depreciation expense, other deferred charges and noncurrent assets and prepayments	6
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	8
CECONY | Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	81	$ 88
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 17	$ 10
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)	85 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)	5.30%	5.30%	2.20%
Average depreciation rates (percent)	3.20%	3.00%	2.90%
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_7

Summary of Significant Accounting Policies and Other Matters - Capitalized Cost of Utility Plant (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 3,880	$ 3,562
Held for future use	92	75
Construction work in progress	2,474	1,937
NET UTILITY PLANT	42,024	39,751
Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	572	591
Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	3,786	3,634
Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	21,481	20,676
General
Public Utility, Property, Plant and Equipment [Line Items]
General	52	43
Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	9,206	8,617
Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,854	1,813
General
Public Utility, Property, Plant and Equipment [Line Items]
General	2,507	2,365
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
General	3,585	3,271
Held for future use	84	67
Construction work in progress	2,320	1,812
NET UTILITY PLANT	39,552	37,412
CECONY | Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	572	591
CECONY | Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	3,496	3,380
CECONY | Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	20,366	19,602
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	52	43
CECONY | Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	8,522	7,961
CECONY | Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,854	1,813
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 2,286	$ 2,143

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, 2020	Dec. 31, 2019	Dec. 31, 2018
Finite-Lived Intangible Assets [Line Items]
Accumulated amortization	$ 228,000,000	$ 126,000,000
Amortization of intangible assets	102,000,000	99,000,000	$ 14,000,000
Amortization expense, 2020	102,000,000
Amortization expense, 2021	102,000,000
Amortization expense, 2022	102,000,000
Amortization expense, 2023	102,000,000
Amortization expense, 2024	102,000,000
Impairment charges	0	0	$ 2,000,000
Net non-utility plant	46,555,000,000	43,889,000,000
Intangible assets	1,460,000,000	1,557,000,000
Long-term debt	22,349,000,000	19,973,000,000
Other Intangible Assets
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	3,000,000
Accumulated amortization	8,000,000	7,000,000
Power Purchase Agreements
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	1,457,000,000	1,554,000,000
Accumulated amortization	$ 220,000,000	$ 119,000,000

Summary of Significant Accoun_9

Summary of Significant Accounting Policies and Other Matters - Recoverable Energy Costs (Details)	12 Months Ended
	Dec. 31, 2020
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) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)mi	Dec. 30, 2020USD ($)	Dec. 31, 2019USD ($)	Jan. 31, 2016
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	$ 465		$ 397
Deferred income plan assets	92		81
Other	3		2
Total investments	$ 1,816		2,065
Stagecoach
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	50.00%
Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 530		530
Mountain Valley Pipeline | Minimum
Schedule of Equity Method Investments [Line Items]
Aggregate project cost	5,800
Mountain Valley Pipeline | Maximum
Schedule of Equity Method Investments [Line Items]
Aggregate project cost	$ 6,000
Mountain Valley Pipeline | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Expected ownership percentage	8.80%
CET | Stagecoach
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 845		924
CET | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	342		602
CET | New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	69		59
CECONY
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	439		371
Deferred income plan assets	92		81
Other	10		9
Total investments	541		461
CECONY | CET | Stagecoach
Schedule of Equity Method Investments [Line Items]
Equity method investments	0		0
CECONY | CET | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	0		0
CECONY | CET | New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	0		0
CET Gas | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 530		$ 530
Equity method investment, ownership percentage	11.30%
Carrying value of investment	$ 342	$ 662
Number of miles in pipeline construction | mi	77
Long -term firm transportation contract period	20 years
Cash flows discount rate	8.30%
Impairment loss	$ 320
Expected reduction in equity interest	8.80%
Impairment loss, after tax	$ 223
CET Gas | Mountain Valley Pipeline | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage				12.50%

Summary of Significant Accou_11

Summary of Significant Accounting Policies and Other Matters - Pension and Other Postretirement Benefits (Details)	12 Months Ended
	Dec. 31, 2020
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)	20.00%

Summary of Significant Accou_12

Summary of Significant Accounting Policies and Other Matters - Research and Development Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Research and Development Expenses [Line Items]
Research and development costs	$ 24	$ 24	$ 24
CECONY
Research and Development Expenses [Line Items]
Research and development costs	$ 23	$ 23	$ 23

Summary of Significant Accou_13

Summary of Significant Accounting Policies and Other Matters - Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Net income	$ 1,101	$ 1,343	$ 1,382	$ 1,525
Weighted average common shares outstanding – basic (in shares)	334.8	328.5	311.7
Add: Incremental shares attributable to effect of potentially dilutive securities (in shares)	0.9	1	1.2
Adjusted weighted average common shares outstanding – diluted (in shares)	335.7	329.5	312.9
Net income per common share — basic (in dollars per share)	$ 3.29	$ 4.09	$ 4.43
Net income per common share — diluted (in dollars per share)	$ 3.28	$ 4.08	$ 4.42

Summary of Significant Accou_14

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, 2020	Dec. 31, 2019	Dec. 31, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	$ 18,213	$ 16,839	$ 15,425
BALANCE AS OF BEGINNING OF PERIOD	18,022
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
BALANCE AS OF END OF PERIOD	18,847	18,022
BALANCE AS OF END OF PERIOD	19,065	18,213	16,839
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(19)	(16)	(26)
BALANCE AS OF END OF PERIOD	(25)	(19)	(16)
Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	(11)	(10)	4
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	5	7	6
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
OCI before reclassifications, tax	4	(6)	3
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(2)	(2)	(2)
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(19)	(16)	(26)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
BALANCE AS OF END OF PERIOD	(25)	(19)	(16)
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	14,147	12,910	12,439
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	1
BALANCE AS OF END OF PERIOD	14,849	14,147	12,910
CECONY | Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(6)	(5)	(6)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	1
BALANCE AS OF END OF PERIOD	(7)	(6)	(5)
CECONY | Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	(3)	(3)	0
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	2	2	1
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	$ 1
OCI before reclassifications, tax	$ 1	$ (1)

Summary of Significant Accou_15

Summary of Significant Accounting Policies and Other Matters - Reconciliation of Cash, Temporary Investments and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	$ 1,272	$ 981
Restricted cash	164	236
Total cash, temporary cash investments and restricted cash	1,436	1,217	$ 1,006	$ 844
Cash Collateral Held For Project Finance Agreements | Clean Energy Businesses
Cash and Cash Equivalents [Line Items]
Restricted cash	164	236
CECONY
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	1,067	933
Restricted cash	0	0
Total cash, temporary cash investments and restricted cash	$ 1,067	$ 933	$ 818	$ 730

Regulatory Matters - Summary of

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Electric) (Details) - USD ($)	1 Months Ended	12 Months Ended					36 Months Ended
	Dec. 31, 2016	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2022	Dec. 31, 2019	Dec. 31, 2016	Dec. 31, 2023
Public Utilities, General Disclosures [Line Items]
Revenues		$ 12,246,000,000	$ 12,574,000,000	$ 12,337,000,000	$ 12,033,000,000
Deferred revenues		41,000,000	17,000,000	20,000,000	87,000,000			$ 17,000,000
Deferred revenues		$ (599,000,000)	(599,000,000)					(599,000,000)
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
CECONY
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 46,000,000
Revenues		10,647,000,000	10,821,000,000	10,680,000,000
Deferred revenues		(523,000,000)	(477,000,000)					(477,000,000)
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues								75,000,000
Actual earnings adjustment mechanism incentives		34,000,000	43,000,000	25,000,000	13,000,000
Other earnings incentives		5,000,000	5,000,000	5,000,000
Deferred revenues		242,000,000	169,000,000	(6,000,000)	45,000,000			169,000,000
Negative revenue adjustments		5,000,000	15,000,000	0	0
Cost reconciliation, deferred net regulatory liabilities		288,000,000	10,000,000	189,000,000	35,000,000			10,000,000
Deferred regulatory asset (liability)		4,100,000	(11,800,000)	(400,000)	400,000			$ (11,800,000)
Earnings sharing, threshold limit		$ 0	0	0	$ 0
Earnings sharing, positive adjustment						$ 5,700,000
Common Equity Ratio, Percentage								4800.00%
Increase in gas base rate due to expiration of temporary credit under the prior rate plan	$ 48,000,000
Recovery or refund of energy costs, deferral period								10 years
Deferrals for property taxes limitation from rates (percent)									90.00%
Recovery deferral (percent)		80.00%
Maximum deferral (percent)		30.00%
CECONY | Electric | NYSPSC
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 199,000,000
CECONY | Electric | Service Termination
Public Utilities, General Disclosures [Line Items]
Revenues			$ 7,000,000	$ 3,000,000
CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues							$ 75,000,000
Weighted average cost of capital (after-tax) (percent)							661.00%
Authorized return on common equity (percent)							880.00%
Earnings sharing (percent)										9.30%
Common Equity Ratio, Percentage							4800.00%
Maximum deferral (percent)										15.00%
Income tax benefit to be credited to customers resulting from TCJA							$ 377,000,000
CECONY | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 195,000,000
Utilities operating expense, depreciation and amortization								$ 84,000,000
Potential earnings adjustment mechanism incentives								28,000,000
Average rate base								$ 18,902,000,000
Weighted average cost of capital (after-tax) (percent)								6.82%
Authorized return on common equity (percent)								900.00%
Actual return on common equity (percent)								9.30%
Earnings sharing (percent)		9.50%
Cost of long-term debt rate		4.93%
Recovery of energy efficiency and savings program costs								$ 20,500,000
Deferral, annual maximum (not more than) (percent)									10.00%
CECONY | Electric | Year 1 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								21,689,000,000
CECONY | Electric | Year 1 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								126,000,000
CECONY | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								376,000,000
CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 113,000,000
Utilities operating expense, depreciation and amortization							267,000,000
Potential earnings adjustment mechanism incentives							69,000,000
Potential penalties (annually)							450,000,000
Average rate base							$ 21,660,000,000
Actual return on common equity (percent)							8.50%
Cost of long-term debt rate										463.00%
Amount of cost recovery							$ 206,000,000
CECONY | Electric | Year 1 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							24,491,000,000
CECONY | Electric | Year 1 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							572,000,000
CECONY | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 155,000,000
Utilities operating expense, depreciation and amortization								83,000,000
Potential earnings adjustment mechanism incentives								47,000,000
Average rate base								$ 19,530,000,000
Weighted average cost of capital (after-tax) (percent)								6.80%
Actual return on common equity (percent)								9.36%
Cost of long-term debt rate		4.88%
Recovery of energy efficiency and savings program costs								$ 49,000,000
Deferral, annual maximum (not more than) (percent)									7.50%
CECONY | Electric | Year 2 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								22,338,000,000
CECONY | Electric | Year 2 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								257,000,000
CECONY | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								341,000,000
CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 370,000,000
Utilities operating expense, depreciation and amortization							269,000,000
Potential earnings adjustment mechanism incentives							74,000,000
Potential penalties (annually)							461,000,000
Average rate base							22,783,000,000
Amount of cost recovery							245,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							25,092,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							740,000,000
CECONY | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 155,000,000
Utilities operating expense, depreciation and amortization								69,000,000
Potential earnings adjustment mechanism incentives								64,000,000
Average rate base								$ 20,277,000,000
Weighted average cost of capital (after-tax) (percent)								6.73%
Actual return on common equity (percent)								8.82%
Cost of long-term debt rate		4.74%
Recovery of energy efficiency and savings program costs								$ 107,500,000
Deferral, annual maximum (not more than) (percent)									5.00%
CECONY | Electric | Year 3 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								23,002,000,000
CECONY | Electric | Year 3 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								415,000,000
CECONY | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								$ 352,000,000
CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 326,000,000
Utilities operating expense, depreciation and amortization							272,000,000
Potential earnings adjustment mechanism incentives							79,000,000
Potential penalties (annually)							476,000,000
Average rate base							23,926,000,000
Amount of cost recovery							251,000,000
CECONY | Electric | Year 3 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							25,708,000,000
CECONY | Electric | Year 3 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							806,000,000
Annually | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							126,000,000
Annually | CECONY | Electric | Scenario, Forecast | Deferred Project Costs
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization							48,000,000
Over Five Years | CECONY | Electric | Scenario, Forecast | Deferred Project Costs
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization							238,000,000
Over Three Years | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							377,000,000
Protected Portion | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							1,663,000,000
Protected Portion | CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							49,000,000
Protected Portion | CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							50,000,000
Protected Portion | CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							53,000,000
Unprotected Portion | CECONY | Electric | Scenario, Forecast
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 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							$ 157,000,000

Regulatory Matters - Summary _2

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Gas) (Details) - USD ($)	1 Months Ended	12 Months Ended				36 Months Ended
	Dec. 31, 2016	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2022	Dec. 31, 2019	Dec. 31, 2023
Public Utilities, General Disclosures [Line Items]
Revenues		$ 12,246,000,000	$ 12,574,000,000	$ 12,337,000,000	$ 12,033,000,000
Deferred revenues		41,000,000	17,000,000	20,000,000	87,000,000		$ 17,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Revenues		10,647,000,000	10,821,000,000	10,680,000,000
CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve							15.00%
Other earnings incentives		3,000,000	7,000,000	6,000,000	7,000,000
Deferred revenues		27,000,000	10,000,000	12,000,000	3,000,000		$ 10,000,000
Negative revenue adjustments		0	0	4,000,000	5,000,000
Cost reconciliation, deferred net regulatory liabilities		91,000,000	18,000,000	44,000,000	2,000,000		18,000,000
Deferred regulatory asset (liability)		$ (24,700,000)	(1,700,000)	(2,200,000)	(2,200,000)		$ (1,700,000)
Earnings sharing (percent)		9.50%
Earnings sharing, threshold limit		$ 0	0	0	$ 0
Common Equity Ratio, Percentage							4800.00%
Increase in gas base rate due to expiration of temporary credit under the prior rate plan	$ 41,000,000
CECONY | Gas | Maximum
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained			65,000,000				$ 65,000,000
CECONY | Gas | Gas Leak Backlog, Leak Prone Pipe and Service Terminations
Public Utilities, General Disclosures [Line Items]
Revenues		$ 13,000,000	$ 9,000,000	$ 5,000,000
CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve						15.00%
Earnings sharing (percent)								9.30%
Common Equity Ratio, Percentage						4800.00%
Income tax benefit to be credited to customers resulting from TCJA						$ 63,000,000
CECONY | Gas | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained						65,000,000
CECONY | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes							(5,000,000)
Utilities operating expense, depreciation and amortization							39,000,000
Potential incentives if performance targets are met							7,000,000
Potential penalties (annually)							68,000,000
Average rate base							$ 4,841,000,000
Weighted average cost of capital (after-tax) (percent)							6.82%
Authorized return on common equity (percent)							900.00%
Actual return on common equity (percent)							9.22%
Cost of long-term debt rate		4.93%
CECONY | Gas | Year 1 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 5,844,000,000
CECONY | Gas | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							27,000,000
CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						84,000,000
Utilities operating expense, depreciation and amortization						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)						661.00%
Authorized return on common equity (percent)						880.00%
Actual return on common equity (percent)						8.40%
Cost of long-term debt rate								463.00%
CECONY | Gas | Year 1 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 8,108,000,000
CECONY | Gas | Year 1 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						142,000,000
CECONY | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes							92,000,000
Utilities operating expense, depreciation and amortization							37,000,000
Potential incentives if performance targets are met							8,000,000
Potential penalties (annually)							63,000,000
Average rate base							$ 5,395,000,000
Weighted average cost of capital (after-tax) (percent)							6.80%
Actual return on common equity (percent)							9.04%
Cost of long-term debt rate		4.88%
CECONY | Gas | Year 2 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 6,512,000,000
CECONY | Gas | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							57,000,000
CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						122,000,000
Utilities operating expense, depreciation and amortization						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
CECONY | Gas | Year 2 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						8,808,000,000
CECONY | Gas | Year 2 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						183,000,000
CECONY | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes							90,000,000
Utilities operating expense, depreciation and amortization							36,000,000
Potential incentives if performance targets are met							8,000,000
Potential penalties (annually)							70,000,000
Average rate base							$ 6,005,000,000
Weighted average cost of capital (after-tax) (percent)							6.73%
Actual return on common equity (percent)							8.72%
Cost of long-term debt rate		4.74%
CECONY | Gas | Year 3 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 7,177,000,000
CECONY | Gas | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 100,000,000
CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						167,000,000
Utilities operating expense, depreciation and amortization						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
CECONY | Gas | Year 3 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						9,510,000,000
CECONY | Gas | Year 3 | Scenario, Forecast | 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		15.00%
NYSPSC | Maximum
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
Annually | 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 Ten Years | CECONY | Gas | Year 1 | Scenario, Forecast
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 | Year 2 | Scenario, Forecast
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 | Year 3 | Scenario, Forecast
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 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA						63,000,000
Protected Portion | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						725,000,000
Protected Portion | CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						14,000,000
Protected Portion | CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						14,000,000
Protected Portion | CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						12,000,000
Unprotected Portion | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						107,000,000
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 Five Years | CECONY | Gas | Scenario, Forecast
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
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2016	Dec. 31, 2014
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization							$ 37,000,000
Regulatory liabilities, amortization period							3 years
Negative revenue adjustments	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Cost reconciliation, deferred net regulatory liabilities				$ 14,000,000	8,000,000		$ 8,000,000	$ 42,000,000
Cost reconciliation, deferred net regulatory assets	35,000,000	8,000,000	1,000,000			17,000,000
Increase (decrease) in regulatory liabilities	0	0	0			(100,000)
Authorized return on common equity (percent)							930.00%
Earnings sharing (percent)				9.90%
Earnings sharing, threshold limit	$ 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
Common Equity Ratio, Percentage							4800.00%
Other regulatory liabilities				$ 8,000,000
Difference in property taxes (percent)							90.00%
Deferral, annual maximum (not more than) (percent)							10.00%
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%
Year 1 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 1,752,000,000
Year 1 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							6,000,000
Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							1,000,000
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%
Year 2 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 1,732,000,000
Year 2 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							11,000,000
Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							1,000,000
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%
Year 3 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 1,720,000,000
Year 3 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							25,000,000
Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							1,000,000
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]
Actual return on common equity (percent)							7.91%

Regulatory Matters - Summary _4

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Electric) (Details) - USD ($)	1 Months Ended	12 Months Ended						24 Months Ended	36 Months Ended
	Jan. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Oct. 31, 2017	Dec. 31, 2021	Oct. 31, 2018	Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Deferred revenues		$ 41,000,000	$ 17,000,000	$ 20,000,000	$ 87,000,000
Deferred revenues		$ 599,000,000	599,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
O&R
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 3,000,000
O&R | Electric
Public Utilities, General Disclosures [Line Items]
Deferred revenues						$ 6,300,000
Deferred revenues		6,000,000	100,000	500,000	11,200,000
Negative revenue adjustments			0	0	0	1,250,000
Deferral of net increase (decrease) to regulatory assets		30,300,000	4,300,000	5,000,000	3,200,000	7,400,000	$ 300,000
Net utility plant reconciliations			1,400,000	(1,900,000)	(1,900,000)	2,200,000
Authorized return on common equity (percent)								900.00%
Earnings sharing (percent)								9.60%
Earnings sharing, threshold limit				300,000	6,100,000
Common Equity Ratio, Percentage								4800.00%
Deferred storm and property reserve deficiency, noncurrent								$ 59,300,000
Deferred storm and property reserve deficiency, recovery period								5 years
Deferred storm and property reserve deficiency not recovered								$ 1,000,000
Deferred Regulatory Asset (Liability)		400,000
O&R | Electric | NYSPSC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Common Equity Ratio, Percentage	50.00%
Requested rate increase (decrease), amount	$ 24,500,000
Return on common equity (percent)	9.50%
O&R | Electric | Property Tax and Interest Rate Reconciliations
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable								4,000,000
O&R | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes								9,300,000
Amortization to income of net regulatory assets								(8,500,000)
Net utility plant reconciliations								928,000,000
Average rate base								$ 763,000,000
Weighted average cost of capital (after-tax) (percent)								7.10%
Actual return on common equity (percent)								10.80%
Cost of long-term debt (percent)								5.42%
Deferred storm and property reserve deficiency, noncurrent								$ 11,850,000
Rate exclusion amount with balance below regulatory threshold								1,000,000
O&R | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								4,000,000
O&R | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes								8,800,000
Amortization to income of net regulatory assets								(9,400,000)
Net utility plant reconciliations								970,000,000
Average rate base								$ 805,000,000
Weighted average cost of capital (after-tax) (percent)								7.06%
Actual return on common equity (percent)								9.70%
Cost of long-term debt (percent)								5.35%
Rate exclusion amount with balance below regulatory threshold								$ 9,000,000
O&R | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								4,000,000
O&R | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes								0
Amortization to income of net regulatory assets								0
Average rate base								$ 805,000,000
Weighted average cost of capital (after-tax) (percent)								7.06%
Actual return on common equity (percent)								7.20%
Cost of long-term debt (percent)								5.35%
O&R | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								$ 4,000,000
O&R | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)									900.00%
Earnings sharing (percent)											9.60%
Common Equity Ratio, Percentage									4800.00%
Deferrals for property taxes limitation from rates (percent)									90.00%
O&R | Electric | Scenario, Forecast | 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%
Actual return on common equity (percent)									9.60%
Cost of long-term debt (percent)									5.17%
Requested rate increase (decrease), amount									$ 8,600,000
Deferral, annual maximum (not more than) (percent)									10.00%
O&R | Electric | Scenario, Forecast | Year 1 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,008,000,000
O&R | Electric | Scenario, Forecast | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									48,000,000
O&R | Electric | Scenario, Forecast | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									4,400,000
O&R | Electric | Scenario, Forecast | 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)									7.50%
O&R | Electric | Scenario, Forecast | Year 2 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,032,000,000
O&R | Electric | Scenario, Forecast | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									58,000,000
O&R | Electric | Scenario, Forecast | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									4,400,000
O&R | Electric | Scenario, Forecast | 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									500,000
Average rate base									$ 948,000,000
Weighted average cost of capital (after-tax) (percent)									6.96%
Cost of long-term debt (percent)									5.14%
Requested rate increase (decrease), amount									$ 12,200,000
Deferral, annual maximum (not more than) (percent)									5.00%
O&R | Electric | Scenario, Forecast | Year 3 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,083,000,000
O&R | Electric | Scenario, Forecast | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									61,000,000
O&R | Electric | Scenario, Forecast | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									4,500,000
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Deferred revenues			6,300,000	1,700,000	6,200,000
Deferred revenues		500,000	800,000			800,000
Negative revenue adjustments		200,000	100,000	0	0	$ 0
Authorized return on common equity (percent)										9.00%
Earnings sharing (percent)										9.60%
Earnings sharing, threshold limit				$ 200,000	$ 4,000,000
Common Equity Ratio, Percentage										4800.00%
Deferred Regulatory Asset (Liability)			400,000
O&R | Gas | NYSPSC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Common Equity Ratio, Percentage	50.00%
Requested rate increase (decrease), amount	$ 9,800,000
Return on common equity (percent)	9.50%
O&R | Gas | Property Tax and Interest Rate Reconciliations
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable										$ 14,000,000
O&R | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes										16,400,000
Amortization to income of net regulatory assets										(1,700,000)
Net utility plant reconciliations										492,000,000
Average rate base										$ 366,000,000
Weighted average cost of capital (after-tax) (percent)										7.10%
Actual return on common equity (percent)										11.20%
Cost of long-term debt (percent)										5.42%
Rate exclusion amount with balance below regulatory threshold										$ 500,000
O&R | Gas | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)										3,700,000
O&R | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes										16,400,000
Amortization to income of net regulatory assets										(2,100,000)
Net utility plant reconciliations										518,000,000
Average rate base										$ 391,000,000
Weighted average cost of capital (after-tax) (percent)										7.06%
Actual return on common equity (percent)										9.70%
Cost of long-term debt (percent)										5.35%
Rate exclusion amount with balance below regulatory threshold										$ 4,200,000
O&R | Gas | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)										4,700,000
O&R | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes										5,800,000
Amortization to income of net regulatory assets										(2,500,000)
Net utility plant reconciliations										546,000,000
Average rate base										$ 417,000,000
Weighted average cost of capital (after-tax) (percent)										7.06%
Actual return on common equity (percent)										8.10%
Cost of long-term debt (percent)										5.35%
Rate exclusion amount with balance below regulatory threshold										$ 7,200,000
O&R | Gas | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)										$ 4,900,000
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Potential earnings adjustment mechanism incentives									$ 300,000
Authorized return on common equity (percent)									9.00%
Earnings sharing (percent)											9.60%
Common Equity Ratio, Percentage									4800.00%
O&R | Gas | Scenario, Forecast | 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%
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 | Scenario, Forecast | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									20,000,000
O&R | Gas | Scenario, Forecast | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									5,500,000
O&R | Gas | Scenario, Forecast | 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 | Scenario, Forecast | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									24,000,000
O&R | Gas | Scenario, Forecast | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									5,700,000
O&R | Gas | Scenario, Forecast | 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%
Cost of long-term debt (percent)									5.14%
Requested rate increase (decrease), amount									$ 1,000,000
O&R | Gas | Scenario, Forecast | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									25,000,000
O&R | Gas | Scenario, Forecast | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									$ 6,000,000
Energy Efficiency | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		2,600,000
Energy Efficiency | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		300,000
Service Termination | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		500,000	200,000
Service Termination | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 500,000	$ 700,000

Regulatory Matters - Summary _5

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Gas) (Details) - USD ($)	1 Months Ended	12 Months Ended					36 Months Ended
	Jan. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2021	Oct. 31, 2018	Dec. 31, 2022	Dec. 31, 2015
Public Utilities, General Disclosures [Line Items]
Deferred revenues		$ 599,000,000	$ 599,000,000
Deferred revenues		$ 41,000,000	17,000,000	$ 20,000,000	$ 87,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
O&R
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 3,000,000
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Deferred revenues		500,000	800,000			$ 800,000
Deferred revenues			6,300,000	1,700,000	6,200,000
Negative revenue adjustments		200,000	100,000	0	0	0
Cost reconciliation, deferred net regulatory liabilities		1,800,000	6,000,000	7,400,000	3,500,000					$ 4,500,000
Cost reconciliation, deferred net regulatory assets						$ 6,600,000
Deferred regulatory asset (liability)			(400,000)
Authorized return on common equity (percent)								9.00%
Earnings sharing (percent)								9.60%
Earnings sharing, threshold limit				$ 200,000	$ 4,000,000
Common Equity Ratio, Percentage								4800.00%
O&R | Gas | NYSPSC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Common Equity Ratio, Percentage	50.00%
Requested rate increase (decrease), amount	$ 9,800,000
Return on common equity (percent)	9.50%
O&R | Gas | Property Tax and Interest Rate Reconciliations
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable								$ 14,000,000
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained									$ 4,000,000
Share in variances in annual revenue retained (percent)							20.00%
Potential earnings adjustment mechanism incentives							$ 300,000
Authorized return on common equity (percent)							9.00%
Earnings sharing (percent)									9.60%
Common Equity Ratio, Percentage							4800.00%
O&R | Gas | Scenario, Forecast | Customers
Public Utilities, General Disclosures [Line Items]
Share in variances in annual revenue retained (percent)							80.00%
O&R | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes								16,400,000
Amortization to income of net regulatory assets								1,700,000
Net utility plant reconciliations								492,000,000
Average rate base								$ 366,000,000
Weighted average cost of capital (after-tax) (percent)								7.10%
Actual return on common equity (percent)								11.20%
Cost of long-term debt (percent)								5.42%
Rate exclusion amount with balance below regulatory threshold								$ 500,000
O&R | Gas | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								3,700,000
O&R | Gas | Year 1 | Scenario, Forecast
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%
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 | Year 1 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							20,000,000
O&R | Gas | Year 1 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							5,500,000
O&R | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes								16,400,000
Amortization to income of net regulatory assets								2,100,000
Net utility plant reconciliations								518,000,000
Average rate base								$ 391,000,000
Weighted average cost of capital (after-tax) (percent)								7.06%
Actual return on common equity (percent)								9.70%
Cost of long-term debt (percent)								5.35%
Rate exclusion amount with balance below regulatory threshold								$ 4,200,000
O&R | Gas | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								4,700,000
O&R | Gas | Year 2 | Scenario, Forecast
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 | Year 2 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							24,000,000
O&R | Gas | Year 2 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							5,700,000
O&R | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes								5,800,000
Base rate change through surcharge								10,600,000
Amortization to income of net regulatory assets								2,500,000
Net utility plant reconciliations								546,000,000
Average rate base								$ 417,000,000
Weighted average cost of capital (after-tax) (percent)								7.06%
Actual return on common equity (percent)								8.10%
Cost of long-term debt (percent)								5.35%
Rate exclusion amount with balance below regulatory threshold								$ 7,200,000
O&R | Gas | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								$ 4,900,000
O&R | Gas | Year 3 | Scenario, Forecast
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%
Cost of long-term debt (percent)							5.14%
Requested rate increase (decrease), amount							$ 1,000,000
O&R | Gas | Year 3 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							25,000,000
O&R | Gas | Year 3 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							$ 6,000,000
Energy Efficiency | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		300,000
Service Termination | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 500,000	$ 700,000

Regulatory Matters - Summary _6

Regulatory Matters - Summary of Utilities Rate Plans (RECO) (Details) - RECO - USD ($) $ in Millions	1 Months Ended			3 Months Ended	9 Months Ended	35 Months Ended
	Feb. 29, 2020	Apr. 30, 2017	Jan. 31, 2016	Mar. 31, 2017	Dec. 31, 2017	Jan. 31, 2020
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization						$ 0.2
Regulatory liabilities, amortization period						3 years
Amortization to income of net regulatory assets	$ 4.8					$ 25.6
Regulatory assets, amortization period	4 years					4 years
Average rate base	$ 229.9					$ 178.7
Weighted average cost of capital (after-tax) (percent)	711.00%					7.47%
Authorized return on common equity (percent)	950.00%					960.00%
Cost of long-term debt (percent)	488.00%					537.00%
Common Equity Ratio, Percentage	4832.00%					4970.00%
FERC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ 17.7		$ 11.8
Return on common equity (percent)					10.00%
Electric
Public Utilities, General Disclosures [Line Items]
Plan electric system storm hardening amount			$ 15.7
Plan period (years)			3 years
Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes	$ 12					$ 1.7
Actual return on common equity (percent)	5.40%					7.50%
Year 2
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)						5.70%

Regulatory Matters - COVID-19 R

Regulatory Matters - COVID-19 Regulatory Matters (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Public Utilities, General Disclosures [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic		$ 78
CECONY
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		46
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic		73
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		34	$ 43	$ 25	$ 13
O&R
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		3
COVID-19
Public Utilities, General Disclosures [Line Items]
Deferred costs	$ 0.5	0.5
COVID-19 | CECONY
Public Utilities, General Disclosures [Line Items]
Estimated forgone revenues	61	3
COVID-19 | CECONY | Electric and Gas Transmission Projects
Public Utilities, General Disclosures [Line Items]
Reserve adjustments		73
Allowance for credit loss, write-off		18
COVID-19 | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Reserve adjustments		2
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic		1
Allowance for credit loss, write-off		1
Residential Customers | COVID-19 | CECONY
Public Utilities, General Disclosures [Line Items]
Deferred revenue	54.9	$ 54.9
Summer Cooling Credit Program | Residential Customers | COVID-19 | CECONY
Public Utilities, General Disclosures [Line Items]
Cost of the program, recovery period		5 years
Expected deferred revenue	$ 63.4	$ 63.4

Regulatory Matters - Additional

Regulatory Matters - Additional Information (Details) customer in Thousands, $ in Thousands

Jul. 13, 2019customer

Nov. 30, 2020USD ($)claim

Aug. 31, 2020USD ($)customer

Mar. 31, 2018customer

Apr. 30, 2017USD ($)

Mar. 31, 2017USD ($)

Dec. 31, 2017

Dec. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Dec. 31, 2018USD ($)

Dec. 31, 2022USD ($)

Jun. 30, 2020USD ($)

Apr. 30, 2020USD ($)

Mar. 31, 2020USD ($)

Jul. 31, 2019USD ($)

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

$ 4,513,000

$ 4,827,000

Return On regulatory assets

$ 1,696,000

$ 1,188,000

Other Customer-Provided Capital rate

2.65%

4.20%

Future Income Tax

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

$ 2,207,000

$ 2,426,000

Net Unbilled Revenue Deferrals

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

198,000

199,000

RECO | Electric | Hurricane

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

44

Restoration costs

17,000

RECO | FERC

Public Utilities, General Disclosures [Line Items]

Requested rate increase (decrease), amount

$ 17,700

$ 11,800

Return on common equity (percent)

10.00%

CECONY

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

4,094,000

4,427,000

Return On regulatory assets

1,509,000

1,054,000

CECONY | Future Income Tax

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

2,062,000

2,275,000

CECONY | Net Unbilled Revenue Deferrals

Public Utilities, General Disclosures [Line Items]

Regulatory liabilities

198,000

199,000

CECONY | Electric | Hurricane

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

209

Restoration costs

134,000

Operation and maintenance expenses

15,000

Operation and maintenance expenses charged against a storm reserve

84,000

Capital expenditures

29,000

Removal costs

6,000

CECONY | Electric | Tropical Storm [Member]

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

330

Restoration costs

153,000

Operation and maintenance expenses

18,000

Operation and maintenance expenses charged against a storm reserve

77,000

Capital expenditures

58,000

Property damage, clean up and response costs

7,500

Estimate of possible loss

$ 102,300

Alleged number of claims, violations | claim

33

CECONY | Electric | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Income tax benefit to be credited to customers resulting from TCJA

$ 377,000

TCJA, net benefit amortization, allocation period

3 years

CECONY | Electric | Scenario, Forecast | Protected Portion

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 1,663,000

CECONY | Electric | Scenario, Forecast | Unprotected Portion

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

5 years

Increase in regulatory liability resulting from TCJA

$ 784,000

CECONY | Gas | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Income tax benefit to be credited to customers resulting from TCJA

$ 63,000

TCJA, net benefit amortization, allocation period

2 years

CECONY | Gas | Scenario, Forecast | Protected Portion

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 725,000

CECONY | Gas | Scenario, Forecast | Unprotected Portion

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

5 years

Increase in regulatory liability resulting from TCJA

$ 107,000

CECONY | NYSPSC | Steam

Public Utilities, General Disclosures [Line Items]

Income tax benefit to be credited to customers resulting from TCJA

$ 185,000

$ 15,000

Tax credit, amortization period

3 years

CECONY | NYSPSC | Electric | Hurricane

Public Utilities, General Disclosures [Line Items]

Loss contingency accrual

$ 5,600

Settlement agreement amount

$ 5,600

O&R | Electric | Hurricane

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

93

Restoration costs

43,000

O&R | Electric | Tropical Storm [Member]

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

200

Restoration costs

34,000

Operation and maintenance expenses charged against a storm reserve

26,000

Capital expenditures

8,000

Property damage, clean up and response costs

2,900

Estimate of possible loss

$ 19,000

Alleged number of claims, violations | claim

38

O&R | Electric and Gas | Scenario, Forecast

Public Utilities, General Disclosures [Line Items]

Income tax benefit to be credited to customers resulting from TCJA

$ 22,000

TCJA, net benefit amortization, allocation period

3 years

O&R | Electric and Gas | Scenario, Forecast | Protected Portion

Public Utilities, General Disclosures [Line Items]

Increase in regulatory liability resulting from TCJA

$ 123,000

O&R | Electric and Gas | Scenario, Forecast | Unprotected Portion

Public Utilities, General Disclosures [Line Items]

TCJA, net benefit amortization, allocation period

15 years

Increase in regulatory liability resulting from TCJA

$ 30,000

O&R | NYSPSC | Electric | Hurricane

Public Utilities, General Disclosures [Line Items]

Loss contingency accrual

$ 850

Settlement agreement amount

$ 850

Manhattan | CECONY | Electric

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

72

Estimate of possible loss

$ 24,800

Brooklyn | CECONY | Electric

Public Utilities, General Disclosures [Line Items]

Number of customers affected with interrupted service | customer

30

Cumulative catch-up adjustment to revenue, modification of contract

(15,000)

Manhattan Steam Main Rupture | CECONY | NYSPSC

Public Utilities, General Disclosures [Line Items]

Property damage, clean up and response costs

17,000

Capital and retirement costs

9,000

Loss contingency accrual

$ 3,000

$ 15,000

Violations Of Gas Operator Qualification, Performance, And Inspection Requirements | CECONY | NYSPSC | Gas

Public Utilities, General Disclosures [Line Items]

Loss contingency accrual

$ 10,000

$ 5,000

Regulatory Matters - Regulatory

Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	$ 6,195	$ 4,859
Regulatory assets – current	266	128
Total Regulatory Assets	6,461	4,987
Regulatory assets not earning return	4,766	3,799
Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3,241	2,541
Regulatory assets not earning return	3,241	2,541
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	865	732
Regulatory assets not earning return	855	727
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	356	321
Regulatory assets not earning return	336	296
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	315	71
Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	241	219
Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	195	77
MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	188	248
System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	124	131
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	120	83
Regulatory assets not earning return	120	83
COVID - 19 Deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	115	0
Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	62	75
Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	36	39
Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	32	35
Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	25	19
Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	21	28
Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	21	22
Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	20	21
Non-wire alternative projects
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	14
Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	3
Regulatory assets not earning return	0	3
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	200	180
Regulatory assets not earning return	24	21
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	190	128
Regulatory assets not earning return	190	128
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	76	0
CECONY
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	5,745	4,487
Regulatory assets – current	244	113
Total Regulatory Assets	5,989	4,600
Regulatory assets not earning return	4,481	3,546
CECONY | Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3,065	2,403
Regulatory assets not earning return	3,065	2,403
CECONY | Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	791	647
Regulatory assets not earning return	781	647
CECONY | Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	342	308
Regulatory assets not earning return	323	285
CECONY | Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	272	47
CECONY | Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	239	210
CECONY | Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	83	0
CECONY | MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	188	248
CECONY | System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	124	130
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	111	76
Regulatory assets not earning return	111	76
CECONY | COVID - 19 Deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	113	0
CECONY | Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	62	75
CECONY | Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	36	39
CECONY | Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	32	35
CECONY | Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	25	19
CECONY | Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	19	26
CECONY | Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	21	22
CECONY | Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	19
CECONY | Non-wire alternative projects
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	14
CECONY | Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	3
Regulatory assets not earning return	0	3
CECONY | Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	186	166
Regulatory assets not earning return	24	20
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	177	113
Regulatory assets not earning return	177	112
CECONY | Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	$ 67	$ 0

Regulatory Matters - Regulato_2

Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 4,513	$ 4,827
Regulatory liabilities—current	36	102
Total Regulatory Liabilities	4,549	4,929
Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	2,207	2,426
Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,090	989
TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	295	471
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	198	199
Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	137	173
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	85	75
System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	64	48
Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	36	45
BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	27	27
Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	21	10
Sales and use tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	16	8
Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	15	22
Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	11	9
Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5	8
Workers’ compensation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	3	0
Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1	122
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	302	195
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	28	44
Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	8	34
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	0	24
CECONY
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	4,094	4,427
Regulatory liabilities—current	11	63
Total Regulatory Liabilities	4,105	4,490
CECONY | Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	2,062	2,275
CECONY | Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	932	843
CECONY | TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	286	454
CECONY | Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	198	199
CECONY | Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	137	173
CECONY | Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	46	46
CECONY | System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	57	44
CECONY | Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	35	45
CECONY | BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	25	26
CECONY | Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	21	10
CECONY | Sales and use tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	16	8
CECONY | Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	15
CECONY | Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	0
CECONY | Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5	8
CECONY | Workers’ compensation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	3	0
CECONY | Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	118
CECONY | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	261	163
CECONY | Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	4	12
CECONY | Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	7	34
CECONY | Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	$ 0	$ 17

Capitalization - Common Stock (

Capitalization - Common Stock (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Dec. 31, 2020	Jan. 31, 2020	Jun. 30, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	May 31, 2019	Dec. 31, 2017
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)	500,000,000			500,000,000
Common stock, shares outstanding (in shares)	342,297,534			342,297,534	332,629,597
Treasury shares (in shares)	23,210,700			23,210,700	23,210,700
Value of shares issued				$ 640	$ 825	$ 705
Proceeds from issuance of common stock				$ 640	$ 825	$ 705
0.65 Percent Debentures Due 2023 | Debentures
Schedule of Capitalization [Line Items]
Interest rate	0.65%			0.65%
Proceeds from sale of aggregate principal amount	$ 650
Term Loan Due July 2020 | Term Loan
Schedule of Capitalization [Line Items]
Repayments of debt	$ 820
Common Stock
Schedule of Capitalization [Line Items]
Common stock, shares outstanding (in shares)	342,000,000			342,000,000	333,000,000	321,000,000		310,000,000
Shares issued (in shares)	7,200,000			9,000,000	12,000,000	11,000,000
Value of shares issued				$ 1	$ 1
Proceeds from issuance of common stock	$ 553
Forward Contract | Common Stock
Schedule of Capitalization [Line Items]
Common stock, shares subject to forward sale agreements (in shares)							5,800,000
Shares issued (in shares)		1,050,000	4,750,000
Value of shares issued		$ 88	$ 400
CECONY
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)	340,000,000			340,000,000
Common stock, shares outstanding (in shares)	235,488,094			235,488,094	235,488,094
Treasury shares (in shares)	21,976,200			21,976,200	21,976,200
CECONY | Common Stock
Schedule of Capitalization [Line Items]
Common stock, shares outstanding (in shares)	235,000,000			235,000,000	235,000,000	235,000,000		235,000,000

Capitalization - Dividends (Det

Capitalization - Dividends (Details)	12 Months Ended
	Dec. 31, 2020
Debt Disclosure [Abstract]
Percentage limitation for income available for dividends (not more than)	100.00%
Rolling average calculation of income available for dividends (years)	2 years

Capitalization - Schedule of Lo

Capitalization - Schedule of Long-Term Debt Maturities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
2021	$ 1,967
2022	437
2023	966
2024	385
2025	315
Long-term debt	22,349	$ 19,973
Long-term debt due within one year		1,446
CECONY
Debt Instrument [Line Items]
2021	640
2022	0
2024	250
2025	0
Long-term debt	$ 16,789	14,964
Long-term debt due within one year		$ 350

Capitalization - Long-term Debt

Capitalization - Long-term Debt, Additional Information (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Long-term debt	$ 22,349,000,000	$ 19,973,000,000
CECONY
Debt Instrument [Line Items]
Long-term debt	16,789,000,000	14,964,000,000
CECONY | Tax-Exempt Debt
Debt Instrument [Line Items]
Debt instrument, face amount	450,000,000
Long-term debt	$ 450,000,000	$ 450,000,000

Capitalization - Carrying Amoun

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Unamortized debt expense	$ 215	$ 178
Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	22,349	19,973
Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	26,808	22,738
CECONY
Debt Instrument [Line Items]
Unamortized debt discount	176	151
CECONY | Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	16,789	14,964
CECONY | Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	$ 20,974	$ 17,505

Capitalization - Significant De

Capitalization - Significant Debt Covenants (Details)	12 Months Ended
	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Debt Instrument [Line Items]
Long-term debt	$ 22,349,000,000	$ 19,973,000,000
Maximum ratio of consolidated debt to consolidated total capital	0.53
CECONY
Debt Instrument [Line Items]
Long-term debt	$ 16,789,000,000	14,964,000,000
Maximum ratio of consolidated debt to consolidated total capital	0.56
Term Loan
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.65
Covenant principal balance amount limit	$ 150,000,000
Term Loan | Term Loan Due June 2021
Debt Instrument [Line Items]
Debt instrument, face amount	825,000,000
Long-term debt	675,000,000
Term Loan | CECONY
Debt Instrument [Line Items]
Covenant principal balance amount limit	$ 150,000,000
Notes
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.675
Covenant principal balance amount limit	$ 100,000,000
Notes | CECONY
Debt Instrument [Line Items]
Covenant principal balance amount limit	100,000,000
Tax-Exempt Debt | CECONY
Debt Instrument [Line Items]
Debt instrument, face amount	450,000,000
Long-term debt	$ 450,000,000	$ 450,000,000
Maximum ratio of consolidated debt to consolidated total capital	0.65

Short-Term Borrowing (Details)

Short-Term Borrowing (Details)	12 Months Ended
	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 1,705,000,000	$ 1,692,000,000
Weighted average interest rate	0.30%	2.00%
Loans outstanding under credit agreement	$ 0	$ 0
Maximum ratio of consolidated debt to consolidated total capital	0.53
Minimum percentage of liens on assets	5.00%
Failure to pay, maximum aggregate limit	$ 150,000,000
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	$ 1,660,000,000	$ 1,137,000,000
Weighted average interest rate	0.30%	2.00%
Maximum ratio of consolidated debt to consolidated total capital	0.56
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
Variable Rate Construction Loan Facility Due November 2021 | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	613,000,000
Variable Rate Construction Loan Facility Due November 2021 | Revolving Credit | Clean Energy Businesses
Short-term Debt [Line Items]
Debt instrument, face amount	$ 165,000,000

Pension Benefits - Total Period

Pension Benefits - Total Periodic Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 293	$ 250	$ 290
Interest cost on projected benefit obligation	549	601	561
Expected return on plan assets	(1,034)	(988)	(1,033)
Recognition of net actuarial loss	699	518	688
Recognition of prior service credit	(16)	(17)	(17)
TOTAL PERIODIC BENEFIT COST	491	364	489
Cost capitalized	(130)	(108)	(127)
Reconciliation to rate level	(250)	(15)	(92)
Total credit recognized	111	241	270
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	274	232	272
Interest cost on projected benefit obligation	515	564	525
Expected return on plan assets	(980)	(936)	(979)
Recognition of net actuarial loss	661	492	651
Recognition of prior service credit	(19)	(19)	(19)
TOTAL PERIODIC BENEFIT COST	451	333	450
Cost capitalized	(123)	(102)	(119)
Reconciliation to rate level	(239)	(12)	(100)
Total credit recognized	$ 89	$ 219	$ 231

Pension Benefits - Schedule of

Pension Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 397
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	465	$ 397
Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	16,792	14,449	$ 15,536
Service cost – excluding administrative expenses	288	245	286
Interest cost on projected benefit obligation	549	601	561
Net actuarial loss/(gain)	2,281	2,191	(1,219)
Plan amendments	0	15	0
Benefits paid	(945)	(709)	(715)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	18,965	16,792	14,449
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	15,608	13,450	14,274
Actual return on plan assets	1,927	2,556	(536)
Employer contributions	475	350	473
Benefits paid	(945)	(709)	(715)
Administrative expenses	(43)	(39)	(46)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	17,022	15,608	13,450
FUNDED STATUS	(1,943)	(1,184)	(999)
Unrecognized net loss	3,330	2,604	2,464
Unrecognized prior service costs/(credits)	(156)	(173)	(205)
Accumulated benefit obligation	16,768	15,015	13,030
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	371
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	439	371
CECONY | Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	15,750	13,542	14,567
Service cost – excluding administrative expenses	269	228	267
Interest cost on projected benefit obligation	515	564	525
Net actuarial loss/(gain)	2,154	2,076	(1,159)
Plan amendments	0	0	0
Benefits paid	(867)	(660)	(658)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	17,821	15,750	13,542
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	14,790	12,744	13,519
Actual return on plan assets	1,830	2,425	(507)
Employer contributions	435	318	434
Benefits paid	(867)	(660)	(658)
Administrative expenses	(41)	(37)	(44)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	16,147	14,790	12,744
FUNDED STATUS	(1,674)	(960)	(798)
Unrecognized net loss	3,145	2,466	2,338
Unrecognized prior service costs/(credits)	(183)	(202)	(222)
Accumulated benefit obligation	$ 15,676	$ 14,010	$ 12,161

Pension Benefits - Additional I

Pension Benefits - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Pension liability	$ 759,000,000	$ 185,000,000
Investments value	465,000,000	397,000,000
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets and liabilities for future income taxes, net	734,000,000
Charge to OCI	8,000,000
Investments value	17,022,000,000	15,608,000,000	$ 13,450,000,000	$ 14,274,000,000
Accumulated benefit obligation	16,768,000,000	15,015,000,000	13,030,000,000
Defined benefit plan, bond amount (excess of)	50,000,000
Estimated future employer contributions	480,000,000
Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	414,000,000	395,000,000
CECONY
Defined Benefit Plan Disclosure [Line Items]
Pension liability	714,000,000	162,000,000
Investments value	439,000,000	371,000,000
CECONY | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets and liabilities for future income taxes, net	696,000,000
Charge to OCI	2,000,000
Investments value	16,147,000,000	14,790,000,000	12,744,000,000	$ 13,519,000,000
Accumulated benefit obligation	15,676,000,000	14,010,000,000	$ 12,161,000,000
Estimated future employer contributions	441,000,000
CECONY | Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 377,000,000	$ 360,000,000

Pension Benefits - Schedule o_2

Pension Benefits - Schedule of Assumptions (Details)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CECONY
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.80%	3.80%	4.25%
Rate of compensation increase	3.80%	4.25%	4.25%
O&R
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.20%	3.20%	4.00%
Rate of compensation increase	3.20%	4.00%	4.00%
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations	2.55%	3.35%	4.25%
Interest crediting rate for cash balance plan	3.00%	3.30%	4.00%
Discount rate, net periodic benefit cost	3.35%	4.25%	3.70%
Interest crediting rate for cash balance plan	3.30%	4.00%	4.10%
Expected return on plan assets	7.00%	7.00%	7.50%

Pension Benefits - Schedule o_3

Pension Benefits - Schedule of Expected Benefit Payments (Details) - Pension Benefits $ in Millions	Dec. 31, 2020USD ($)
Defined Benefit Plan Disclosure [Line Items]
2020	$ 764
2021	776
2022	793
2023	807
2024	821
2026-2030	4,295
CECONY
Defined Benefit Plan Disclosure [Line Items]
2020	706
2021	718
2022	733
2023	747
2024	760
2026-2030	$ 3,992

Pension Benefits - Schedule o_4

Pension Benefits - Schedule of Plan Assets Allocations (Details) - Pension Benefits	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	100.00%
Plan Assets Percentage	100.00%	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	51.00%	51.00%	51.00%
Equity Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	45.00%
Equity Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	55.00%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	38.00%	38.00%	39.00%
Debt Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	33.00%
Debt Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	43.00%
Real Estate
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	11.00%	11.00%	10.00%
Real Estate | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	10.00%
Real Estate | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	14.00%

Pension Benefits - Schedule o_5

Pension Benefits - Schedule of Fair Value of Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 465	$ 397
Private Equity
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Real Estate
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 17,022	$ 15,608	$ 13,450	$ 14,274
Pension Benefits | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,202	3,652
Pension Benefits | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,693	3,354
Pension Benefits | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,424	1,496
Pension Benefits | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,535	3,260
Pension Benefits | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	188	173
Pension Benefits | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,067	955
Pension Benefits | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	459	326
Pension Benefits | Private Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	635	555
Pension Benefits | Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,880	1,806
Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	292	270
Pension Benefits | Total Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(254)	(250)
Pension Benefits | Pending Activities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(99)	11
Pension Benefits | Fair Value, Inputs, Level 1 and 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	14,568	13,216
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	(213)	(208)
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	17,121	15,597
Pension Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,946	7,006
Pension Benefits | Level 1 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,202	3,652
Pension Benefits | Level 1 | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,693	3,354
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	51
Pension Benefits | Level 1 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(116)	(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	7,830	6,896
Pension Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	6,622	6,210
Pension Benefits | Level 2 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 2 | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,424	1,496
Pension Benefits | Level 2 | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,535	3,260
Pension Benefits | Level 2 | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	188	173
Pension Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,067	955
Pension Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	408	326
Pension Benefits | Level 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(97)	(98)
Pension Benefits | Level 2 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	6,525	6,112
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	2,807	2,631
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	$ (41)	$ (42)

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, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 52	$ 49	$ 45
CECONY
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 43	$ 42	$ 39

Other Postretirement Benefits -

Other Postretirement Benefits - Net Periodic Postretirement Benefit Costs (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 21	$ 18	$ 20
Interest cost on accumulated other postretirement benefit obligation	37	44	42
Expected return on plan assets	(66)	(66)	(73)
Recognition of net actuarial loss/(gain)	37	(9)	8
Recognition of prior service credit	(3)	(2)	(6)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	26	(15)	(9)
Cost capitalized	(9)	(7)	(8)
Reconciliation to rate level	(17)	12	8
Total credit recognized	0	(10)	(9)
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	16	13	14
Interest cost on accumulated other postretirement benefit obligation	31	36	34
Expected return on plan assets	(54)	(54)	(63)
Recognition of net actuarial loss/(gain)	36	(10)	3
Recognition of prior service credit	(2)	(2)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	27	(17)	(14)
Cost capitalized	(7)	(5)	(6)
Reconciliation to rate level	(25)	7	9
Total credit recognized	$ (5)	$ (15)	$ (11)

Other Postretirement Benefits_2

Other Postretirement Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 397
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	465	$ 397
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	371
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	439	371
Other Postretirement Benefits
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,357	1,114	$ 1,219
Service cost	21	18	20
Interest cost on accumulated other postretirement benefit obligation	37	44	42
Amendments	0	(14)	0
Net actuarial loss/(gain)	74	264	(70)
Benefits paid and administrative expenses, net of subsidies	(117)	(110)	(135)
Participant contributions	53	41	38
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,425	1,357	1,114
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	1,026	885	1,039
Actual return on plan assets	142	198	(66)
Employer contributions	7	7	6
Employer group waiver plan subsidies	20	23	34
Participant contributions	53	40	37
Benefits paid	(133)	(127)	(165)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	1,115	1,026	885
FUNDED STATUS	(310)	(331)	(229)
Unrecognized net loss/(gain)	115	155	14
Unrecognized prior service costs	(16)	(19)	(8)
Other Postretirement Benefits | CECONY
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,154	913	985
Service cost	16	13	14
Interest cost on accumulated other postretirement benefit obligation	31	36	34
Amendments	0	0	0
Net actuarial loss/(gain)	63	252	(32)
Benefits paid and administrative expenses, net of subsidies	(107)	(100)	(125)
Participant contributions	52	40	37
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,209	1,154	913
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	872	759	893
Actual return on plan assets	117	165	(54)
Employer contributions	4	6	6
Employer group waiver plan subsidies	19	22	32
Participant contributions	51	40	37
Benefits paid	(123)	(120)	(155)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	940	872	759
FUNDED STATUS	(269)	(282)	(154)
Unrecognized net loss/(gain)	114	149	(2)
Unrecognized prior service costs	$ (1)	$ (3)	$ (5)

Other Postretirement Benefits_3

Other Postretirement Benefits - Additional Information (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in liability for other postretirement benefits	$ (21)	$ 102
Increase (decrease) in regulatory liabilities	$ 36
Health care cost trend rate for net periodic benefit cost, current	5.20%	5.40%	5.60%
Health care cost trend rate for net periodic benefit cost	4.50%
Health care cost trend rate for benefit obligations, current	7.04%	5.20%	5.40%
Health care cost trend rate for benefit obligations	4.50%
Expected contributions	$ 6
Clean Energy Businesses, Con Edison Transmission and RECO
Defined Benefit Plan Disclosure [Line Items]
Credit to OCI (net of taxes) for unrecognized net losses	2
CECONY
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in liability for other postretirement benefits	(13)	$ 128
Increase (decrease) in regulatory liabilities	33
Expected contributions	$ 3

Other Postretirement Benefits_4

Other Postretirement Benefits - Schedule of Actuarial Assumptions (Details) - Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Expected Return on Plan Assets	6.80%	6.80%	7.50%
CECONY
Defined Benefit Plan Disclosure [Line Items]
Discount Rate, Benefit Obligations	2.25%	3.10%	4.15%
Discount Rate, Net Periodic Benefit Cost	3.10%	4.15%	3.55%
O&R
Defined Benefit Plan Disclosure [Line Items]
Discount Rate, Benefit Obligations	2.55%	3.35%	4.30%
Discount Rate, Net Periodic Benefit Cost	3.35%	4.30%	3.70%

Other Postretirement Benefits_5

Other Postretirement Benefits - Schedule of Expected Benefit Payments (Details) - Other Postretirement Benefits $ in Millions	Dec. 31, 2020USD ($)
Defined Benefit Plan Disclosure [Line Items]
2020	$ 84
2021	84
2022	84
2023	84
2024	84
2026-2030	409
CECONY
Defined Benefit Plan Disclosure [Line Items]
2020	76
2021	75
2022	75
2023	75
2024	75
2026-2030	$ 358

Other Postretirement Benefits_6

Other Postretirement Benefits - Schedule of Plan Assets Allocations (Details) - Other Postretirement Benefits - CECONY	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	100.00%
Plan Assets Percentage	100.00%	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	54.00%	54.00%	52.00%
Equity Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	42.00%
Equity Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	80.00%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	46.00%	46.00%	48.00%
Debt Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	20.00%
Debt Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	58.00%

Other Postretirement Benefits_7

Other Postretirement Benefits - Schedule of Fair Values of Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 465	$ 397
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,115	1,026	$ 885	$ 1,039
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	842	758
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	448	404
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	367	331
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	27	23
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	213	208
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	1,055	966
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	41	42
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	19	18
Other Postretirement Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	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	0	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	116	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	116	110
Other Postretirement Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	842	758
Other Postretirement Benefits | Level 2 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	448	404
Other Postretirement Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	367	331
Other Postretirement Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	27	23
Other Postretirement Benefits | Level 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	97	98
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	$ 939	$ 856

Environmental Matters - Accrued

Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Site Contingency [Line Items]
Accrued Liabilities	$ 857	$ 734
Regulatory assets	6,461	4,987
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	752	640
Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	105	94
Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	857	734
Regulatory assets	865	732
CECONY
Site Contingency [Line Items]
Accrued Liabilities	780	654
Regulatory assets	5,989	4,600
CECONY | Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	676	561
CECONY | Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	104	93
CECONY | Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	780	654
Regulatory assets	$ 791	$ 647

Environmental Matters - Environ

Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 33	$ 19
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 32	$ 13

Environmental Matters - Additio

Environmental Matters - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)
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	$ 40
Superfund Sites | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	2,700
Superfund Sites | CECONY
Site Contingency [Line Items]
Remediation cost estimate	38
Superfund Sites | CECONY | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	$ 2,600

Environmental Matters - Accru_2

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Site Contingency [Line Items]
Regulatory Liabilities	$ (4,549)	$ (4,929)
Regulatory assets	6,461	4,987
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers' Compensation
Site Contingency [Line Items]
Accrued liability	72	78
Regulatory Liabilities	(3)
Regulatory assets		3
CECONY
Site Contingency [Line Items]
Regulatory Liabilities	(4,105)	(4,490)
Regulatory assets	5,989	4,600
CECONY | Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY | Workers' Compensation
Site Contingency [Line Items]
Accrued liability	68	73
Regulatory Liabilities	$ (3)
Regulatory assets		$ 3

Material Contingencies - Manhat

Material Contingencies - Manhattan Explosion and Fire (Details) $ in Millions	Mar. 12, 2014buildingpeople	Feb. 28, 2017USD ($)	Dec. 31, 2020USD ($)lawsuit	Oct. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 4,513		$ 4,827
Settlement of gas proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 21		$ 10
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
Insurance receivable				$ 40
Manhattan Explosion and Fire | Settlement of gas proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability		$ 27

Material Contingencies - Guaran

Material Contingencies - Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Guarantee obligations maximum exposure	$ 2,042	$ 1,831

Material Contingencies - Total

Material Contingencies - Total Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 2,042	$ 1,831
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	570
Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	753
Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	649
Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	70
0 – 3 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,228
0 – 3 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	393
0 – 3 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	480
0 – 3 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	285
0 – 3 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	70
4 – 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	237
4 – 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	177
4 – 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	51
4 – 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	9
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	577
> 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	222
> 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	355
> 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, 2020	Dec. 31, 2019
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,042	$ 1,831
Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Estimated project cost percentage	175.00%
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	Dec. 31, 2020	Dec. 31, 2019
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,042	$ 1,831
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

Electricity Purchase Agreemen_3

Electricity Purchase Agreements - Summary of Estimated Capacity and Other Fixed Payments (Details) $ in Millions	Dec. 31, 2020USD ($)
Long-term Contract for Purchase of Electric Power [Line Items]
2021	$ 141
2022	106
2023	68
2024	53
2025	54
All Years Thereafter	487
CECONY
Long-term Contract for Purchase of Electric Power [Line Items]
2021	138
2022	106
2023	68
2024	53
2025	54
All Years Thereafter	$ 487

Electricity Purchase Agreemen_4

Electricity Purchase Agreements - Summary of Capacity, Energy and Other Fixed Payments (Details) - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 139	$ 231	$ 318
Indian Point
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	0	0	6
Astoria Generating Company
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	26	116	179
Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	113	115	124
Cogen Technologies
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 0	$ 0	$ 9

Leases - Additional Information

Leases - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Lease, renewal term	5 years
Assets under finance leases	$ 3	$ 1
Finance leases, accumulated amortization	3	5
Right-of-use asset obtained in exchange for operating lease liability	23	39
CECONY
Lessee, Lease, Description [Line Items]
Assets under finance leases	2
Finance leases, accumulated amortization	1	3
Right-of-use asset obtained in exchange for operating lease liability	$ 11	$ 4
Minimum
Lessee, Lease, Description [Line Items]
Lease, term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Lease, term	40 years

Leases - Lease Cost and Cash Fl

Leases - Lease Cost and Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 85	$ 83
Operating lease cash flows	79	75
CECONY
Lessee, Lease, Description [Line Items]
Operating lease cost	65	64
Operating lease cash flows	$ 61	$ 60

Leases - Other Related Informat

Leases - Other Related Information (Details)	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	19 years 1 month 6 days	19 years 9 months 18 days
Weighted Average Remaining Lease Term, Finance leases	7 years 3 months 18 days	12 years 2 months 12 days
Weighted Average Discount Rate, Operating leases	4.30%	4.30%
Weighted Average Discount Rate, Finance leases	1.80%	3.50%
CECONY
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	13 years	14 years
Weighted Average Remaining Lease Term, Finance leases	4 years	2 years 4 months 24 days
Weighted Average Discount Rate, Operating leases	3.60%	3.60%
Weighted Average Discount Rate, Finance leases	1.30%	4.10%

Leases - Future Minimum Lease P

Leases - Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Operating Leases
2021	$ 79
2022	77
2023	74
2024	75
2025	75
All years thereafter	938
Total future minimum lease payments	1,318
Less: imputed interest	(458)
Total	860
Operating lease liabilities (current)	96	$ 65
Operating lease liabilities (noncurrent)	764	809
Total	860
Finance Leases
2021	1
2022	1
2023	0
2024	0
2025	0
All years thereafter	1
Total future minimum lease payments	3
Less: imputed interest	0
Total	3
Other current liabilities	1
Other noncurrent liabilities	2
Total	3
CECONY
Operating Leases
2021	62
2022	58
2023	57
2024	57
2025	58
All years thereafter	451
Total future minimum lease payments	743
Less: imputed interest	(158)
Total	585
Operating lease liabilities (current)	73	54
Operating lease liabilities (noncurrent)	512	$ 551
Total	585
Finance Leases
2021	1
2022	1
2023	0
2024	0
2025	0
All years thereafter	0
Total future minimum lease payments	2
Less: imputed interest	0
Total	2
Other current liabilities	1
Other noncurrent liabilities	1
Total	$ 2

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Goodwill [Line Items]
Goodwill	$ 446	$ 446
CECONY
Goodwill [Line Items]
Goodwill	245	245
O&R
Goodwill [Line Items]
Goodwill	161	161
O&R Merger
Goodwill [Line Items]
Goodwill	406	406
Gas Storage Company | CET Gas
Goodwill [Line Items]
Goodwill	8	8
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, 2020	Dec. 31, 2019	Dec. 31, 2018
State
Current	$ 7	$ (12)	$ (10)
Deferred	50	96	107
Federal
Current	(2)	0	3
Deferred	42	219	310
Amortization of investment tax credits	(7)	(7)	(9)
Total income tax expense	90	296	401
CECONY
State
Current	6	22	6
Deferred	97	68	82
Federal
Current	41	185	(34)
Deferred	73	63	275
Amortization of investment tax credits	(2)	(3)	(3)
Total income tax expense	$ 215	$ 335	$ 326

Income Tax - Schedule of Differ

Income Tax - Schedule of Differences on Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Deferred tax liabilities:
Property basis differences	$ 7,985	$ 7,699
Regulatory assets:
Unrecognized pension and other postretirement costs	910	712
Environmental remediation costs	243	205
Deferred storm costs	31	22
Other regulatory assets	536	376
Operating lease right-of-use asset	220	231
Equity investments	46	104
Total deferred tax liabilities	9,971	9,349
Deferred tax assets:
Accrued pension and other postretirement costs	504	291
Future income tax	617	678
Other regulatory liabilities	656	702
Superfund and other environmental costs	241	206
Asset retirement obligations	178	135
Operating lease liabilities	211	231
Loss carryforwards	164	108
Tax credits carryforward	1,022	896
Valuation allowance	(22)	(31)
Other	59	47
Total deferred tax assets	3,630	3,263
Net deferred tax liabilities	6,341	6,086
Unamortized investment tax credits	134	141
Net deferred tax liabilities and unamortized investment tax credits	6,475	6,227
CECONY
Deferred tax liabilities:
Property basis differences	6,901	6,640
Regulatory assets:
Unrecognized pension and other postretirement costs	861	674
Environmental remediation costs	222	181
Deferred storm costs	0	0
Other regulatory assets	508	355
Operating lease right-of-use asset	165	169
Equity investments	0	0
Total deferred tax liabilities	8,657	8,019
Deferred tax assets:
Accrued pension and other postretirement costs	427	222
Future income tax	579	638
Other regulatory liabilities	570	622
Superfund and other environmental costs	219	183
Asset retirement obligations	143	102
Operating lease liabilities	165	170
Loss carryforwards	34	0
Tax credits carryforward	0	0
Valuation allowance	0	0
Other	127	103
Total deferred tax assets	2,264	2,040
Net deferred tax liabilities	6,393	5,979
Unamortized investment tax credits	18	21
Net deferred tax liabilities and unamortized investment tax credits	$ 6,411	$ 6,000

Income Tax - Additional Informa

Income Tax - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	$ 21
Unrecognized Tax Benefits	14	$ 13	$ 6	$ 12
Effective income tax rate reconciliation, uncertainty of taxes	3
Unrecognized tax benefits that would have an impact on effective tax rate	14
Unrecognized tax benefits that would have an impact on effective tax rate, net of tax	13
General Business Tax Credit
Operating Loss Carryforwards [Line Items]
Tax credit carryovers	1,022
Tax Year 2018 Through 2013
Operating Loss Carryforwards [Line Items]
Operating loss carryback	29
Net tax refund	2.5
Tax Year 2013
Operating Loss Carryforwards [Line Items]
Discrete income tax benefit	4
State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards, valuation allowance	18
State | New York State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	1,351
State | New York City
Operating Loss Carryforwards [Line Items]
Valuation allowance reversed	$ 9
Deferred tax asset, period of realization	10 years
CECONY
Operating Loss Carryforwards [Line Items]
Unrecognized Tax Benefits	$ 3	$ 2	$ 4	$ 5
Effective income tax rate reconciliation, uncertainty of taxes	1
Unrecognized tax benefits that would have an impact on effective tax rate	$ 3

Income Tax - Schedule of Income

Income Tax - Schedule of Income Tax Reconciliation (Details)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
STATUTORY TAX RATE
Federal	21.00%	21.00%	21.00%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	4.00%	4.00%	4.00%
Taxes attributable to noncontrolling interests	(1.00%)	(1.00%)	0.00%
Cost of removal	2.00%	1.00%	1.00%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)
TCJA deferred tax re-measurement	0	0	0.02
Amortization of excess deferred federal income taxes	(14.00%)	(4.00%)	(3.00%)
Renewable energy credits	(3.00%)	(2.00%)	(1.00%)
Research and development credits	0.00%	(1.00%)	0.00%
Other	(1.00%)	0.00%	0.00%
Effective tax rate	7.00%	17.00%	23.00%
CECONY
STATUTORY TAX RATE
Federal	21.00%	21.00%	21.00%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	5.00%	5.00%	5.00%
Taxes attributable to noncontrolling interests	0.00%	0.00%	0.00%
Cost of removal	1.00%	1.00%	1.00%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)
TCJA deferred tax re-measurement	0	0	0
Amortization of excess deferred federal income taxes	(12.00%)	(4.00%)	(3.00%)
Renewable energy credits	0.00%	0.00%	0.00%
Research and development credits	0.00%	(1.00%)	(1.00%)
Other	1.00%	0.00%	(1.00%)
Effective tax rate	15.00%	21.00%	21.00%

Income Tax - Summary of Unrecog

Income Tax - Summary of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	$ 13	$ 6	$ 12
Additions based on tax positions related to the current year	0	1	2
Additions based on tax positions of prior years	1	10	1
Reductions for tax positions of prior years	0	(2)	(2)
Reductions from expiration of statute of limitations	0	0	(4)
Settlements	0	(2)	(3)
Balance at end of period	14	13	6
CECONY
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	2	4	5
Additions based on tax positions related to the current year	0	1	2
Additions based on tax positions of prior years	1	0	1
Reductions for tax positions of prior years	0	(1)	(1)
Reductions from expiration of statute of limitations	0	0	0
Settlements	0	(2)	(3)
Balance at end of period	$ 3	$ 2	$ 4

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 12,026	$ 12,144	$ 11,928
Revenues	12,246	12,574	12,337	$ 12,033
Other
Disaggregation of Revenue [Line Items]
Revenues	220	430	409
Clean Energy Businesses | Renewables [Member] | Engineering, procurement and construction
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8	14	103
CECONY
Disaggregation of Revenue [Line Items]
Revenues	10,647	10,821	10,680
Operating Segments | Clean Energy Businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	661	646	424
Revenues	736	857	763
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Revenues	75	211	339
Operating Segments | Clean Energy Businesses | Renewables [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	609	575	329
Revenues	609	575	329
Operating Segments | Clean Energy Businesses | Renewables [Member] | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Energy Service [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	52	71	95
Revenues	52	71	95
Operating Segments | Clean Energy Businesses | Energy Service [Member] | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Other Services [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Revenues	75	211	339
Operating Segments | Clean Energy Businesses | Other Services [Member] | Other
Disaggregation of Revenue [Line Items]
Revenues	75	211	339
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	10,518	10,620	10,597
Revenues	10,647	10,821	10,680
Operating Segments | CECONY | Other
Disaggregation of Revenue [Line Items]
Revenues	129	201	83
Operating Segments | CECONY | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8,026	7,913	7,920
Revenues	8,103	8,062	7,971
Operating Segments | CECONY | Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	77	149	51
Operating Segments | CECONY | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,998	2,097	2,052
Revenues	2,036	2,132	2,078
Operating Segments | CECONY | Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	38	35	26
Operating Segments | CECONY | Steam
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	494	610	625
Revenues	508	627	631
Operating Segments | CECONY | Steam | Other
Disaggregation of Revenue [Line Items]
Revenues	14	17	6
Operating Segments | O&R
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	843	874	903
Revenues	862	893	891
Operating Segments | O&R | Other
Disaggregation of Revenue [Line Items]
Revenues	19	19	(12)
Operating Segments | O&R | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	619	627	647
Revenues	629	634	642
Operating Segments | O&R | Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	10	7	(5)
Operating Segments | O&R | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	224	247	256
Revenues	233	259	249
Operating Segments | O&R | Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	9	12	(7)
Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Revenues	(3)	(1)	(1)
Other | Other
Disaggregation of Revenue [Line Items]
Revenues	(3)	(1)	(1)
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, 2020	Dec. 31, 2019	Dec. 31, 2018
Unbilled contract revenue
Beginning balance	$ 29	$ 29	$ 58
Additions	88	86	144
Subtractions	106	86	173
Ending balance	11	29	29
Unearned revenue
Beginning balance	17	20	87
Additions	31	1	38
Subtractions	7	4	105
Ending balance	41	17	20
Contracts with customer, revenue recognized, amount outstanding end of last period	$ 7	$ 4	$ 50

Revenue Recognition - Revenue R

Revenue Recognition - Revenue Recognition, Remaining Performance Obligation (Details) $ in Millions	Dec. 31, 2020USD ($)
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 216
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 181
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing of satisfaction	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 35
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing of satisfaction

Revenue Recognition - Additiona

Revenue Recognition - Additional information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)
Disaggregation of Revenue [Line Items]
Late fee and other fees not collected	$ 64
CECONY
Disaggregation of Revenue [Line Items]
Late fee and other fees not collected	$ 61

Stock-Based Compensation - Addi

Stock-Based Compensation - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit realized from stock options exercised	$ 5,000,000	$ 13,000,000	$ 4,000,000
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)	20.00%
CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit realized from stock options exercised	$ 4,000,000	11,000,000	4,000,000
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	$ 21,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 21,000,000	24,000,000	29,000,000
Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 17,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 18,000,000	22,000,000	28,000,000
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	$ 2,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 1,000,000	1,000,000	1,000,000
Weighted average grant date price per share (in dollars per share)	$ 78
Time-based Awards | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 2,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 1,000,000	$ 1,000,000	$ 1,000,000
Weighted average grant date price per share (in dollars per share)	$ 78
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	50.00%
Factor used for adjustment of Performance awards, low end (percent)	0.00%
Factor used for adjustment of Performance awards, high end (percent)	200.00%
Weighted average grant date price per share (in dollars per share)	$ 79.98
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)	$ 79.70
Non-TSR Portion | Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%
Factor used for adjustment of Performance awards, low end (percent)	0.00%
Factor used for adjustment of Performance awards, high end (percent)	200.00%
Weighted average grant date price per share (in dollars per share)	$ 90.48
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)	$ 89.65
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units issued (in shares)	33,200
Weighted average grant date price per share (in dollars per share)	$ 74.32
Stock Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares purchased on the open market	836,984	747,899	786,385
Weighted average share price per share, on shares purchased on open market (in dollars per share)	$ 79.82	$ 85.45	$ 78.27

Stock-Based Compensation - Stoc

Stock-Based Compensation - Stock-Based Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 17	$ 47	$ 14
Income tax benefit	5	13	4
Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	7	36	3
Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	1	2	2
Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	3
Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	7	7	6
CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	16	40	13
Income tax benefit	4	11	4
CECONY | Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	6	30	3
CECONY | Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	1	2	1
CECONY | Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	3
CECONY | Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 7	$ 6	$ 6

Stock-Based Compensation - Assu

Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate, minimum	0.10%	1.58%	2.48%
Risk-free interest rate, maximum	0.13%	1.59%	2.63%
Expected term (years)	3 years	3 years	3 years
Expected share price volatility, minimum (percent)	30.16%	12.89%	14.76%
Expected share price volatility, maximum (percent)	40.95%	15.51%	17.71%

Stock-Based Compensation - Summ

Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2020$ / sharesshares
Units
Non-vested at beginning of period (in shares) | shares	991,238
Granted (in shares) | shares	329,600
Vested (in shares) | shares	(326,496)
Forfeited (in shares) | shares	(92,818)
Non-vested at end of period (in shares) | shares	901,524
CECONY
Units
Non-vested at beginning of period (in shares) | shares	742,204
Granted (in shares) | shares	249,761
Vested (in shares) | shares	(245,269)
Forfeited (in shares) | shares	(60,225)
Non-vested at end of period (in shares) | shares	686,471
TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 68.15
Granted (in dollars per share)	79.98
Vested (in dollars per share)	73.07
Forfeited (in dollars per share)	73.80
Non-vested at end of period (in dollars per share)	$ 70.11
Adjustment percentage used for Performance awards	50.00%
TSR Portion | CECONY
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 68.06
Granted (in dollars per share)	79.70
Vested (in dollars per share)	72.70
Forfeited (in dollars per share)	73.61
Non-vested at end of period (in dollars per share)	70.15
Non-TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	77.14
Granted (in dollars per share)	90.48
Vested (in dollars per share)	74.57
Forfeited (in dollars per share)	87.98
Non-vested at end of period (in dollars per share)	$ 81.83
Adjustment percentage used for Performance awards	50.00%
Non-TSR Portion | CECONY
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 77.32
Granted (in dollars per share)	89.65
Vested (in dollars per share)	74.76
Forfeited (in dollars per share)	87.73
Non-vested at end of period (in dollars per share)	$ 81.80

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, 2020$ / sharesshares
Units
Non-vested at beginning of period (in shares) | shares	67,250
Granted (in shares) | shares	22,450
Vested (in shares) | shares	(20,750)
Forfeited (in shares) | shares	(1,512)
Non-vested at end of period (in shares) | shares	67,438
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 80.36
Granted (in dollars per share) | $ / shares	78
Vested (in dollars per share) | $ / shares	77.66
Forfeited (in dollars per share) | $ / shares	80.30
Non-vested at end of period (in dollars per share) | $ / shares	$ 80.40
CECONY
Units
Non-vested at beginning of period (in shares) | shares	63,100
Granted (in shares) | shares	20,900
Vested (in shares) | shares	(19,650)
Forfeited (in shares) | shares	(1,512)
Non-vested at end of period (in shares) | shares	62,838
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 80.36
Granted (in dollars per share) | $ / shares	78
Vested (in dollars per share) | $ / shares	77.66
Forfeited (in dollars per share) | $ / shares	80.30
Non-vested at end of period (in dollars per share) | $ / shares	$ 80.42

Financial Information by Busi_3

Financial Information by Business Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Revenues	$ 12,246	$ 12,574	$ 12,337	$ 12,033
Depreciation and amortization	1,920	1,684	1,438
Operating income	2,654	2,676	2,664
Other Income (deductions)	(401)	51	(62)
Interest charges	1,019	991	819
Income taxes on operating income	193	300	406
Total assets	62,895	58,079	53,920
Capital expenditures	4,085	3,676	5,249
Income tax expense (benefit) on non-operating income	(103)	(4)	(5)
Parent Company
Segment Reporting Information [Line Items]
Total assets	21,499	20,638
CECONY
Segment Reporting Information [Line Items]
Revenues	10,647	10,821	10,680
Depreciation and amortization	1,598	1,373	1,276
Operating income	2,310	2,348	2,354
Other Income (deductions)	(171)	(35)	(143)
Total assets	50,967	46,557
Income tax expense (benefit) on non-operating income	(3)	(7)	(2)
Operating segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	736	857	763
Depreciation and amortization	231	226	85
Operating income	215	202	194
Other Income (deductions)	4	5	33
Interest charges	196	186	63
Income taxes on operating income	(43)	(58)	19
Total assets	6,848	6,528	5,821
Capital expenditures	616	248	1,791
Operating segment | Con Edison Transmission
Segment Reporting Information [Line Items]
Revenues	4	4	4
Depreciation and amortization	1	1	1
Operating income	(8)	(6)	(7)
Other Income (deductions)	(215)	104	91
Interest charges	18	25	20
Income taxes on operating income	0	1	(1)
Total assets	1,348	1,618	1,425
Capital expenditures	3	205	248
Operating segment | CECONY
Segment Reporting Information [Line Items]
Revenues	10,647	10,821	10,680
Depreciation and amortization	1,598	1,373	1,276
Operating income	2,310	2,348	2,354
Other Income (deductions)	(171)	(35)	(143)
Interest charges	739	728	689
Income taxes on operating income	218	342	328
Total assets	50,967	46,557	43,108
Capital expenditures	3,246	3,020	3,005
Operating segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	8,103	8,062	7,971
Depreciation and amortization	1,214	1,053	984
Operating income	1,731	1,758	1,799
Other Income (deductions)	(134)	(28)	(110)
Interest charges	535	539	519
Income taxes on operating income	130	239	233
Total assets	35,673	32,988	31,012
Capital expenditures	2,080	1,851	1,861
Operating segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	2,036	2,132	2,078
Depreciation and amortization	294	231	205
Operating income	574	528	478
Other Income (deductions)	(25)	(4)	(23)
Interest charges	164	147	131
Income taxes on operating income	102	99	87
Total assets	12,678	11,090	9,710
Capital expenditures	1,044	1,078	1,050
Operating segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	508	627	631
Depreciation and amortization	90	89	87
Operating income	5	62	77
Other Income (deductions)	(12)	(3)	(10)
Interest charges	40	42	39
Income taxes on operating income	(14)	4	8
Total assets	2,616	2,479	2,386
Capital expenditures	122	91	94
Operating segment | O&R
Segment Reporting Information [Line Items]
Revenues	862	893	891
Depreciation and amortization	90	84	77
Operating income	147	139	132
Other Income (deductions)	(14)	(11)	(19)
Interest charges	41	41	39
Income taxes on operating income	21	21	21
Total assets	3,247	3,006	2,892
Capital expenditures	220	203	205
Operating segment | O&R | Electric
Segment Reporting Information [Line Items]
Revenues	629	634	642
Depreciation and amortization	65	60	56
Operating income	99	98	93
Other Income (deductions)	(10)	(7)	(14)
Interest charges	26	27	25
Income taxes on operating income	13	15	14
Total assets	2,097	2,130	2,036
Capital expenditures	159	142	138
Operating segment | O&R | Gas
Segment Reporting Information [Line Items]
Revenues	233	259	249
Depreciation and amortization	25	24	21
Operating income	48	41	39
Other Income (deductions)	(4)	(4)	(5)
Interest charges	15	14	14
Income taxes on operating income	8	6	7
Total assets	1,150	876	856
Capital expenditures	61	61	67
Other
Segment Reporting Information [Line Items]
Revenues	(3)	(1)	(1)
Depreciation and amortization	0	0	(1)
Operating income	(10)	(7)	(9)
Other Income (deductions)	(5)	(12)	(24)
Interest charges	25	11	8
Income taxes on operating income	(3)	(6)	39
Total assets	485	370	674
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
Segment Reporting Information [Line Items]
Revenues	0	0	0
Inter-segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	0	0	0
Inter-segment | CECONY
Segment Reporting Information [Line Items]
Revenues	(99)	(94)	(98)
Inter-segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	18	17	16
Inter-segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	7	7	7
Inter-segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	$ 74	$ 70	$ 75

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	$ (366)	$ (183)
Gross Amounts Offset	3	17
Net Amounts of Assets/ (Liabilities)	(363)	(166)
Margin deposits	3	9
CECONY
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	(252)	(124)
Gross Amounts Offset	0	17
Net Amounts of Assets/ (Liabilities)	(252)	(107)
Margin deposits	3	8
Clean Energy Businesses | Interest Rate Swap
Net fair value derivative assets/(liabilities)
Notional amount	863	919
Fair Value of Derivative Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(225)	(140)
Gross Amounts Offset	(13)	17
Net Amounts of Assets/ (Liabilities)	(238)	(123)
Fair Value of Derivative Liabilities, Current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(24)	(7)
Fair Value of Derivative Liabilities, Current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(174)	(100)
Gross Amounts Offset	11	19
Net Amounts of Assets/ (Liabilities)	(163)	(81)
Fair Value of Derivative Liabilities, Non-current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(207)	(122)
Gross Amounts Offset	(33)	16
Net Amounts of Assets/ (Liabilities)	(240)	(106)
Fair Value of Derivative Liabilities, Non-current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(82)	(34)
Fair Value of Derivative Liabilities, Non-current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(114)	(80)
Gross Amounts Offset	9	16
Net Amounts of Assets/ (Liabilities)	(105)	(64)
Fair Value of Derivative Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(432)	(262)
Gross Amounts Offset	(46)	33
Net Amounts of Assets/ (Liabilities)	(478)	(229)
Fair Value of Derivative Liabilities | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(288)	(180)
Gross Amounts Offset	20	35
Net Amounts of Assets/ (Liabilities)	(268)	(145)
Fair Value of Derivative Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	44	60
Gross Amounts Offset	14	(3)
Net Amounts of Assets/ (Liabilities)	58	57
Fair Value of Derivative Assets, Current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	20	39
Gross Amounts Offset	(12)	(6)
Net Amounts of Assets/ (Liabilities)	8	33
Fair Value of Derivative Assets, Non-current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	22	19
Gross Amounts Offset	35	(13)
Net Amounts of Assets/ (Liabilities)	57	6
Fair Value of Derivative Assets, Non-current | Interest Rate Swap
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)		1
Fair Value of Derivative Assets, Non-current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	16	17
Gross Amounts Offset	(8)	(12)
Net Amounts of Assets/ (Liabilities)	8	5
Fair Value of Derivative Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	66	79
Gross Amounts Offset	49	(16)
Net Amounts of Assets/ (Liabilities)	115	63
Fair Value of Derivative Assets | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	36	56
Gross Amounts Offset	(20)	(18)
Net Amounts of Assets/ (Liabilities)	$ 16	$ 38

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, 2020	Dec. 31, 2019
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (26)	$ 1
Total deferred gains/(losses)	(301)	(300)
Net deferred gains/(losses)	(327)	(299)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(63)	(12)
Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(2)	(2)
Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	7	25
Other operations and maintenance expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(3)	1
Other interest expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(65)	(36)
Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(26)	4
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	(3)
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(63)	(91)
Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(201)	(142)
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(37)	(67)
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(27)	4
Total deferred gains/(losses)	(277)	(272)
Net deferred gains/(losses)	(304)	(268)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(3)	1
CECONY | Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0
CECONY | Non-utility revenue
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 gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(3)	1
CECONY | Other interest expense
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)	(27)	5
CECONY | Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	(1)
CECONY | Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(64)	(83)
CECONY | Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(177)	(124)
CECONY | Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (36)	$ (65)

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details)	Dec. 31, 2020galMMBTUMWhMW
Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	28,102,230
Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	47,258
Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	286,819,910
Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	7,728,000
CECONY | Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	26,193,800
CECONY | Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	35,400
CECONY | Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	267,380,000
CECONY | Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	7,728,000

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 217
Makeup of net credit exposure with investment-grade counterparties	47
Makeup of net credit exposure independent system operators	103
Makeup of net credit exposure with commodity exchange brokers	27
Makeup of net credit exposure non-investment grade/non-rated counterparties	40
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	16
Makeup of net credit exposure with commodity exchange brokers	$ 16

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, 2020USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 293
Collateral posted	212
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	5
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	101
Derivatives in net asset position additional collateral	25
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	51
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	277
Collateral posted	200
CECONY | Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	0
CECONY | Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	$ 85

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ (19)
Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(10)
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Transfer out of level 3	1	$ 24
Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Transfer out of level 3	1	22
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	675	550
Derivative liabilities	478	229
Recurring | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	550	498
Recurring | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	53	4
Derivative liabilities	46	(22)
Recurring | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(16)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	450	357
Derivative liabilities	7	18
Recurring | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	426	336
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	168	187
Derivative liabilities	402	215
Recurring | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	140	161
Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4	2
Derivative liabilities	23	18
Recurring | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	118	71
Derivative liabilities	372	188
Recurring | Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	19	46
Derivative liabilities	268	145
Recurring | Commodity | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	53	4
Derivative liabilities	46	(22)
Recurring | Commodity | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(16)
Derivative liabilities	(19)	(24)
Recurring | Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	19	4
Derivative liabilities	7	18
Recurring | Commodity | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	15	3
Derivative liabilities	3	15
Recurring | Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	42	61
Derivative liabilities	296	174
Recurring | Commodity | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	20	42
Derivative liabilities	274	147
Recurring | Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4	2
Derivative liabilities	23	18
Recurring | Commodity | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Derivative liabilities	10	7
Recurring | Interest Rate Swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Derivative liabilities	106	41
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		1
Derivative liabilities	106	41
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	557	478
Recurring | Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	531	452
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	431	353
Recurring | Other | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	411	333
Recurring | Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	126	125
Recurring | Other | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	120	119
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, 2020USD ($)$ / kW-month$ / MWh
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (19)
CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(10)
Electricity | Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(20)
Electricity | Forward Capacity Prices | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (11)
Electricity | Forward Capacity Prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	0.06
Electricity | Forward Capacity Prices | Minimum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	0.08
Electricity | Forward Capacity Prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	6.26
Electricity | Forward Capacity Prices | Maximum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	6.26
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	(2.65)
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	0.23
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	7.69
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	1.13

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, 2020	Dec. 31, 2019
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ (16)	$ (13)
Included in earnings	(10)	(5)
Included in regulatory assets and liabilities	(7)	18
Settlements	15	8
Transfer out of level 3	(1)	(24)
Ending Balance	(19)	(16)
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	(6)	(2)
Included in earnings	(5)	0
Included in regulatory assets and liabilities	(4)	17
Settlements	6	1
Transfer out of level 3	(1)	(22)
Ending Balance	$ (10)	$ (6)

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Details) - Clean Energy Businesses - Non-utility revenue - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative assets and liabilities	$ 3	$ 2
Fair value, assets and liabilities measured on recurring basis, change in unrealized gain (loss)	$ 2	$ 2

Variable Interest Entities - Ad

Variable Interest Entities - Additional Information (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2019MW	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Variable Interest Entity [Line Items]
Noncontrolling interest		$ 218	$ 191
Texas Solar 4 | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Generating capacity (MW AC) | MW	40
Texas Solar 4 | Con Edison Development | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Percentage of variable interests (less than)	80.00%
Ownership percentage acquired		20.00%
Tax Equity Projects | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Income (loss)		$ (6)	(64)
Income (loss), after tax		$ (4)	(48)
Tax Equity Projects | Con Edison Development | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Percentage of variable interests (less than)		100.00%
Tax Equity Projects | Tax Equity Investors | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Income (loss)		$ 44	98
Income (loss), after tax		$ 32	$ 74

Variable Interest Entities - Ne

Variable Interest Entities - Net Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Business Acquisition [Line Items]
Noncontrolling interest	$ 218	$ 191
Great Valley Solar
Business Acquisition [Line Items]
Non-utility property, less accumulated depreciation	284	293
Other assets	39	40
Total assets	323	333
Other liabilities	13	17
Total liabilities	13	17
Accumulated depreciation	18	9
Copper Mountain Solar - Mesquite Solar
Business Acquisition [Line Items]
Non-utility property, less accumulated depreciation	446	461
Other assets	176	128
Total assets	622	589
Other liabilities	71	18
Total liabilities	71	18
Accumulated depreciation	30	15
Tax Equity Investors | Great Valley Solar
Business Acquisition [Line Items]
Noncontrolling interest	82	62
Tax Equity Investors | Copper Mountain Solar - Mesquite Solar
Business Acquisition [Line Items]
Noncontrolling interest	$ 134	$ 126

Variable Interest Entities - Su

Variable Interest Entities - Summary of VIEs (Details) - Variable Interest Entity, Not Primary Beneficiary $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)MW
Great Valley Solar
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	200
Maximum Exposure to Loss | $	$ 228
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 | $	$ 417
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

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	$ 576	$ 425
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	191	(1)
Asset retirement obligations, accretion expense	16	14
Asset retirement obligations, liabilities settled	56	38
Asset retirement obligations, reductions	49	44
CECONY
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	508	362
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	186	96
Asset retirement obligations, accretion expense	13	12
Asset retirement obligations, liabilities settled	53	38
Asset retirement obligations, reductions	$ 49	$ 44

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Details) MMBTU in Thousands	12 Months Ended
	Dec. 31, 2020USD ($)MMBTU	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Related Party Transaction [Line Items]
Net assets	$ 18,847,000,000	$ 18,022,000,000
CECONY
Related Party Transaction [Line Items]
Net assets	14,849,000,000	14,147,000,000	$ 12,910,000,000	$ 12,439,000,000
Sale of natural gas	59,000,000	71,000,000	83,000,000
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	$ 34,000,000	33,000,000	$ 28,000,000
CECONY | Affiliated Entity | Financial Electric Capacity Contract | Con Edison Energy
Related Party Transaction [Line Items]
Gain (loss) on financial electric capacity contracts	(1,000,000)	(1,000,000)
O&R
Related Party Transaction [Line Items]
Net assets	807,000,000
Outstanding loans	$ 0	$ 0
CET Electric | NY Transco
Related Party Transaction [Line Items]
Ownership interest, percentage	45.70%
CET Gas | Mountain Valley Pipeline
Related Party Transaction [Line Items]
Percentage of equity interest owned	11.30%
Expected reduction in equity interest	8.80%

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, 2020	Dec. 31, 2019	Dec. 31, 2018
Related Party Transaction [Line Items]
Cost of services provided	$ 128	$ 121	$ 115
Cost of services received	$ 66	$ 64	$ 73

Acquisitions, Investments and_3

Acquisitions, Investments and Dispositions - Sempra Solar (Details) $ / shares in Units, $ in Millions	Dec. 13, 2018USD ($)$ / sharesMW	Dec. 12, 2018USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2020USD ($)
Business Acquisition [Line Items]
Business acquisition, pre-tax gain from interests in projects	$ 131			$ 131
Long-term debt			$ 19,973		$ 22,349
Sempra Solar
Business Acquisition [Line Items]
Ownership percentage	50.00%
Renewable Electric Production Projects | Sempra Solar
Business Acquisition [Line Items]
Project generating capacity (MW AC) | MW	379
Sempra Solar
Business Acquisition [Line Items]
Business acquisition, pre-tax gain from interests in projects	$ 131
Business acquisition, after-tax gain from interests in projects	$ 89
Business acquisition, after-tax gain from interests in projects, per share (in dollars per share) | $ / shares	$ 0.28
Con Edison Development | Sempra Solar
Business Acquisition [Line Items]
Purchase price	$ 1,609
Working capital and other closing adjustments	69
Reclassification adjustment to property, plant and equipment and asset retirement obligations			$ 100
Period available to finalize purchase price allocation			1 year
Acquisition-date fair value of ownership interest held	568	$ 437
Property, plant and equipment acquired	1,354
Intangible assets acquired	878
Noncurrent assets	$ 4
Weighted average amortization period for intangible assets	16 years
Fair value of noncontrolling interest attributable to tax equity investors	$ 100
Sempra Solar | Renewable Electric Production Projects
Business Acquisition [Line Items]
Project generating capacity (MW AC) | MW	981
Long-term debt	$ 568
Asset retirement obligation	$ 28

Acquisitions, Investments and_4

Acquisitions, Investments and Dispositions - Pro Forma Supplemental Information (Details) - USD ($) $ in Millions	Dec. 13, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 01, 2017
Business Combinations [Abstract]
Revenues		$ 12,246	$ 12,574	$ 12,337	$ 12,033
Net income		$ 1,101	$ 1,343	1,382	1,525
If Acquired January 1, 2017 (a)(b)
Revenue				12,655	12,331
Net income				1,279	1,612
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Interest expense				37	38
Business acquisition, pre-tax gain from interests in projects	$ 131				131
Pro Forma
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Income from equity method investment				33	$ 32
Term Loan
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Short-term borrowings				$ 825
Fixed interest rate						4.64%

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, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Income Statements,Captions [Line Items]
Interest expense	$ (1,019)	$ (991)	$ (819)
NET INCOME FOR COMMON STOCK	1,101	1,343	1,382	$ 1,525
Comprehensive Income	$ 1,095	$ 1,340	$ 1,392
Net Income Per Share – Basic (in dollars per share)	$ 3.29	$ 4.09	$ 4.43
Net Income Per Share – Diluted (in dollars per share)	$ 3.28	$ 4.08	$ 4.42
Average Number Of Shares Outstanding—Basic (in shares)	334.8	328.5	311.7
Average Number Of Shares Outstanding—Diluted (in shares)	335.7	329.5	312.9
Parent Company
Condensed Income Statements,Captions [Line Items]
Equity in earnings of subsidiaries	$ 1,105	$ 1,354	$ 1,447
Other income (deductions), net of taxes	56	76	(6)
Interest expense	(60)	(87)	(59)
NET INCOME FOR COMMON STOCK	1,101	1,343	1,382
Comprehensive Income	$ 1,095	$ 1,340	$ 1,392
Net Income Per Share – Basic (in dollars per share)	$ 3.29	$ 4.09	$ 4.43
Net Income Per Share – Diluted (in dollars per share)	3.28	4.08	4.42
Dividends Declared Per Share (in dollars per share)	$ 3.06	$ 2.96	$ 2.86
Average Number Of Shares Outstanding—Basic (in shares)	334.8	328.5	311.1
Average Number Of Shares Outstanding—Diluted (in shares)	335.7	329.5	312.9

Schedule I - Condensed Financ_3

Schedule I - Condensed Financial Information - Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	$ 1,101	$ 1,343	$ 1,382	$ 1,525
Change in Assets:
Taxes receivable	(6)	29	27
Other – net	(134)	54	(62)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,198	3,134	2,695
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,224)	(3,782)	(5,471)
FINANCING ACTIVITIES
Net proceeds of short-term debt	178	(874)	1,989
Issuance of long-term debt	2,925	3,017	3,030
Retirement of long-term debt	(518)	(1,195)	(1,938)
Debt issuance costs	(47)	(32)	(61)
Issuance of common shares for stock plans	58	54	53
Issuance of common shares - public offering	640	825	705
Common stock dividends	(975)	(924)	(842)
NET CASH FLOWS FROM FINANCING ACTIVITIES	2,245	859	2,938
NET CHANGE FOR THE PERIOD	219	211	162
BALANCE AT BEGINNING OF PERIOD	1,217	1,006	844
BALANCE AT END OF PERIOD	1,436	1,217	1,006	844
CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,185	1,250	1,196
Change in Assets:
Other – net	(49)	54	(96)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,693	2,502	2,204
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,416)	(3,124)	(3,306)
FINANCING ACTIVITIES
Net proceeds of short-term debt	523	(55)	1,042
Issuance of long-term debt	2,200	1,300	2,740
Retirement of long-term debt	(350)	(475)	(1,836)
Debt issuance costs	(34)	(21)	(30)
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,857	737	1,190
NET CHANGE FOR THE PERIOD	134	115	88
BALANCE AT BEGINNING OF PERIOD	933	818	730
BALANCE AT END OF PERIOD	1,067	933	818	730
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,101	1,343	1,382
Equity in earnings of subsidiaries	(1,105)	(1,354)	(1,447)
Change in Assets:
Special deposits	0	(3)	(8)
Taxes receivable		25	2
Other – net	654	44	187
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,713	1,029	1,033
INVESTING ACTIVITIES
Contributions to subsidiaries	(626)	(930)	(1,110)
Debt receivable from affiliated companies	400	450	(825)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(226)	(480)	(1,935)
FINANCING ACTIVITIES
Net proceeds of short-term debt	(537)	(783)	164
Issuance of long-term debt	650	825	825
Retirement of long-term debt	(1,178)	(553)	(3)
Debt issuance costs	(3)	0	0
Issuance of common shares for stock plans	58	54	53
Issuance of common shares - public offering	640	825	705
Common stock dividends	(975)	(924)	(842)
NET CASH FLOWS FROM FINANCING ACTIVITIES	(1,345)	(556)	902
NET CHANGE FOR THE PERIOD	142	(7)	0
BALANCE AT BEGINNING OF PERIOD	2	9	9
BALANCE AT END OF PERIOD	144	2	9	$ 9
Parent Company | CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	982	912	846
Parent Company | O&R
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	49	47	46
Parent Company | Clean Energy Businesses
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	21	3	15
Parent Company | Con Edison Transmission
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	$ 11	$ 12	$ 10

Schedule I - Condensed Financ_4

Schedule I - Condensed Financial Information - Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Current Assets
Cash and temporary cash investments	$ 1,272	$ 981
Accounts receivable - customers, less allowance for uncollectible accounts	1,701	1,236
Taxes receivable	26	20
Prepayments	271	260
Other current assets	231	200
TOTAL CURRENT ASSETS	5,301	4,272
Investments in subsidiaries and others	1,816	2,065
Goodwill	446	446
Other noncurrent assets	9,223	7,853
TOTAL ASSETS	62,895	58,079	$ 53,920
Current Liabilities
Long-term debt due within one year		1,446
Term Loan	165	0
Notes payable	1,705	1,692
Accounts payable	1,475	1,164
Accrued taxes	150	76
Other current liabilities	426	371
TOTAL CURRENT LIABILITIES	7,354	6,287
Long-term debt	20,382	18,527
Shareholders’ Equity
Equity	18,847	18,022
TOTAL LIABILITIES AND EQUITY	62,895	58,079
Parent Company
Current Assets
Cash and temporary cash investments	144	2
Accounts receivable - customers, less allowance for uncollectible accounts	1
Taxes receivable	18	18
Term loan receivable from affiliated companies	0	0
Accounts receivable from affiliated companies	1,256	870
Prepayments	62	32
Other current assets	12	12
TOTAL CURRENT ASSETS	1,493	934
Investments in subsidiaries and others	18,670	18,009
Goodwill	406	406
Deferred income tax	55	14
Long-term debt receivable from affiliated companies	875	1,275
Other noncurrent assets	0	0
TOTAL ASSETS	21,499	20,638
Current Liabilities
Long-term debt due within one year	1,178	3
Term Loan	0	0
Notes payable	0	537
Accounts payable	0	0
Accounts payable to affiliated companies	517	595
Accrued taxes	6	2
Other current liabilities	12	10
TOTAL CURRENT LIABILITIES	1,713	1,147
Deferred income tax	0	0
Total Liabilities	1,713	1,147
Long-term debt	939	1,469
Shareholders’ Equity
Common stock, including additional paid-in capital	8,844	8,089
Retained earnings	10,003	9,933
Equity	18,847	18,022
TOTAL LIABILITIES AND EQUITY	$ 21,499	$ 20,638

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, 2020	Dec. 31, 2019	Dec. 31, 2018
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 74	$ 68	$ 70
Charged To Costs And Expenses	72	77	62
Charged To Other Accounts	0	0	0
Deductions	8	(71)	(64)
Balance At End of Period	154	74	68
CECONY
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	68	61	65
Charged To Costs And Expenses	65	72	56
Charged To Other Accounts	0	0	0
Deductions	10	(65)	(60)
Balance At End of Period	$ 143	$ 68	$ 61