Consolidated Edison Co Of New York 10-K 19 Feb 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Billions, except Share data, unless otherwise specified	Dec. 31, 2014	Jan. 30, 2015	Jun. 30, 2014
Document Information [Line Items]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Trading Symbol	ED
Entity Registrant Name	CONSOLIDATED EDISON INC
Entity Central Index Key	1047862
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		292,888,812
Entity Public Float			$16.90
CECONY [Member]
Document Information [Line Items]
Entity Registrant Name	CONSOLIDATED EDISON CO OF NEW YORK INC
Entity Central Index Key	23632
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer

Consolidated_Income_Statement

Consolidated Income Statement (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
OPERATING REVENUES
Electric	$9,114	$8,756	$8,765
Gas	1,933	1,821	1,618
Steam	628	683	596
Non-utility	1,244	1,094	1,209
TOTAL OPERATING REVENUES	12,919	12,354	12,188
OPERATING EXPENSES
Purchased power	3,417	3,099	3,116
Fuel	285	320	310
Gas purchased for resale	811	635	461
Other operations and maintenance	3,294	3,137	3,182
Depreciation and amortization	1,071	1,024	955
Taxes, other than income taxes	1,877	1,895	1,825
TOTAL OPERATING EXPENSES	10,755	10,110	9,849
Gain on sale of solar electric production projects	45
OPERATING INCOME	2,209	2,244	2,339
OTHER INCOME (DEDUCTIONS)
Investment and other income	54	24	18
Allowance for equity funds used during construction	2	4	4
Other deductions	-14	-15	-16
TOTAL OTHER INCOME (DEDUCTIONS)	42	13	6
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,251	2,257	2,345
INTEREST EXPENSE
Interest on long-term debt	587	578	586
Other interest	5	143	20
Allowance for borrowed funds used during construction	-1	-2	-2
NET INTEREST EXPENSE	591	719	604
INCOME BEFORE INCOME TAX EXPENSE	1,660	1,538	1,741
INCOME TAX EXPENSE	568	476	600
NET INCOME	1,092	1,062	1,141
Preferred stock dividend requirements			-3
NET INCOME FOR COMMON STOCK	1,092	1,062	1,138
Net income for common stock per common share - basic	$3.73	$3.62	$3.88
Net income for common stock per common share - diluted	$3.71	$3.61	$3.86
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK	$2.52	$2.46	$2.42
AVERAGE NUMBER OF SHARES OUTSTANDING - BASIC (IN MILLIONS)	292.9	292.9	292.9
AVERAGE NUMBER OF SHARES OUTSTANDING - DILUTED (IN MILLIONS)	294	294.4	294.5
CECONY [Member]
OPERATING REVENUES
Electric	8,437	8,131	8,176
Gas	1,721	1,616	1,415
Steam	628	683	596
TOTAL OPERATING REVENUES	10,786	10,430	10,187
OPERATING EXPENSES
Purchased power	2,091	2,021	1,968
Fuel	285	320	310
Gas purchased for resale	609	532	387
Other operations and maintenance	2,873	2,735	2,788
Depreciation and amortization	991	946	894
Taxes, other than income taxes	1,798	1,816	1,747
TOTAL OPERATING EXPENSES	8,647	8,370	8,094
OPERATING INCOME	2,139	2,060	2,093
OTHER INCOME (DEDUCTIONS)
Investment and other income	22	11	9
Allowance for equity funds used during construction	1	2	2
Other deductions	-12	-12	-13
TOTAL OTHER INCOME (DEDUCTIONS)	11	1	-2
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,150	2,061	2,091
INTEREST EXPENSE
Interest on long-term debt	523	511	525
Other interest	15	11	22
Allowance for borrowed funds used during construction	-1	-1	-2
NET INTEREST EXPENSE	537	521	545
INCOME BEFORE INCOME TAX EXPENSE	1,613	1,540	1,546
INCOME TAX EXPENSE	555	520	529
NET INCOME	1,058	1,020	1,017
Preferred stock dividend requirements			-3
NET INCOME FOR COMMON STOCK	$1,058	$1,020	$1,014

Consolidated_Statement_of_Comp

Consolidated Statement of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
NET INCOME	$1,092	$1,062	$1,141
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	-20	28	5
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	-20	28	5
COMPREHENSIVE INCOME	1,072	1,090	1,146
Cumulative preferred dividends			-3
COMPREHENSIVE INCOME FOR COMMON STOCK	1,072	1,090	1,143
CECONY [Member]
NET INCOME	1,058	1,020	1,017
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	-5	3	-1
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	-5	3	-1
COMPREHENSIVE INCOME	1,053	1,023	1,016
Cumulative preferred dividends			($3)

Consolidated_Statement_of_Cash

Consolidated Statement of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
OPERATING ACTIVITIES
NET INCOME	$1,092	$1,062	$1,141
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,071	1,024	955
Deferred income taxes	518	40	584
Rate case amortization and accruals	102	10	42
Common equity component of allowance for funds used during construction	-2	-4	-4
Net derivative (gains)/losses	128	-74	-68
Pre-tax gains on termination of LILO transactions		-95
Pre-tax gain on sale of solar electric production projects	-45
Other non-cash items (net)	-35	91	52
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	44	-29	-99
Special deposits	312	-257	-13
Materials and supplies, including fuel oil and gas in storage	-10	-33	26
Other receivables and other current assets	4	34	40
Income taxes receivable	-224
Prepayments	-27	23	-14
Accounts payable	-9	-118	111
Pensions and retiree benefits obligations (net)	822	829	903
Pensions and retiree benefits contributions	-584	-887	-870
Accrued taxes	-404	314	-26
Accrued interest	-113	96	-7
Superfund and environmental remediation costs (net)	28	-4	7
Deferred charges, noncurrent assets and other regulatory assets	-339	-141	-337
Deferred credits and other regulatory liabilities	495	627	92
Other current and noncurrent liabilities	7	44	84
Net Cash Flows from Operating Activities	2,831	2,552	2,599
INVESTING ACTIVITIES
Utility construction expenditures	-2,239	-2,339	-1,917
Cost of removal less salvage	-216	-217	-175
Non-utility construction expenditures	-180	-199	-152
Investments in renewable electric production projects	-283	-175	-309
Proceeds from grants related to solar electric production projects	36	93	30
Proceeds from sale of solar electric production projects	108
Restricted cash	15	-22
Proceeds from the termination of LILO transactions		200
NET CASH FLOWS USED IN INVESTING ACTIVITIES	-2,759	-2,659	-2,523
FINANCING ACTIVITIES
Net issuance/(payment) of short-term debt	-651	912	539
Issuance of long-term debt	1,850	919	400
Retirement of long-term debt	-480	-709	-305
Debt issuance costs	-17	-6	-4
Common stock dividends	-739	-721	-709
Issuance of common shares for stock plans, net of repurchases	-10	-8	-9
Preferred stock dividends			-3
Preferred stock redemption			-239
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	-47	387	-330
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	25	280	-254
BALANCE AT BEGINNING OF PERIOD	674	394	648
BALANCE AT END OF PERIOD	699	674	394
Cash paid during the period for:
Interest	561	574	571
Income taxes	633	69	46
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	179	174	254
CECONY [Member]
OPERATING ACTIVITIES
NET INCOME	1,058	1,020	1,017
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	991	946	894
Deferred income taxes	331	222	365
Rate case amortization and accruals	102	10	42
Common equity component of allowance for funds used during construction	-1	-2	-2
Other non-cash items (net)	-33	-80	14
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	59	-15	-131
Materials and supplies, including fuel oil and gas in storage	-12	-15	23
Other receivables and other current assets	35	-88	-40
Prepayments	-24	-21	4
Accounts payable	-79	-58	102
Pensions and retiree benefits obligations (net)	742	803	837
Pensions and retiree benefits contributions	-544	-830	-804
Accrued taxes	-403	207	94
Accrued interest	-22	6
Superfund and environmental remediation costs (net)	32	-4	9
Deferred charges, noncurrent assets and other regulatory assets	-334	-148	-239
Deferred credits and other regulatory liabilities	475	666	100
Other current and noncurrent liabilities	57	24	61
Net Cash Flows from Operating Activities	2,430	2,643	2,346
INVESTING ACTIVITIES
Utility construction expenditures	-2,094	-2,207	-1,788
Cost of removal less salvage	-210	-210	-170
NET CASH FLOWS USED IN INVESTING ACTIVITIES	-2,304	-2,417	-1,958
FINANCING ACTIVITIES
Net issuance/(payment) of short-term debt	-760	789	421
Issuance of long-term debt	1,850	700	400
Retirement of long-term debt	-475	-700	-300
Debt issuance costs	-17	-7	-4
Dividend to parent	-712	-728	-682
Preferred stock dividends			-3
Preferred stock redemption			-239
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	-114	54	-407
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	12	280	-19
BALANCE AT BEGINNING OF PERIOD	633	353	372
BALANCE AT END OF PERIOD	645	633	353
Cash paid during the period for:
Interest	504	500	513
Income taxes	748	163	62
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$151	$116	$201

Consolidated_Balance_Sheet

Consolidated Balance Sheet (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
CURRENT ASSETS
Cash and temporary cash investments	$699		$674
Special deposits	8		327
Accounts receivable - customers, less allowance for uncollectible accounts	1,201		1,251
Other receivables, less allowance for uncollectible accounts	133		240
Income taxes receivable	224
Accrued unbilled revenue	500		514
Fuel oil, gas in storage, materials and supplies, at average cost	372		363
Prepayments	163		136
Regulatory assets	148		29
Deferred tax assets - current	128		122
Other current assets	278		235
TOTAL CURRENT ASSETS	3,854		3,891
INVESTMENTS	816		461
UTILITY PLANT AT ORIGINAL COST
General	2,465		2,336
TOTAL	35,909		33,474
Less: Accumulated depreciation	7,614		7,072
Net	28,295		26,402
Construction work in progress	1,031		1,393
NET UTILITY PLANT	29,326		27,795
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	388		605
Construction work in progress	113		36
NET PLANT	29,827		28,436
OTHER NONCURRENT ASSETS
Goodwill	429		429
Intangible assets, less accumulated amortization of $4 in 2014 and 2013	3		4
Regulatory assets	9,156		7,201
Other deferred charges and noncurrent assets	223		225
TOTAL OTHER NONCURRENT ASSETS	9,811		7,859
TOTAL ASSETS	44,308		40,647
CURRENT LIABILITIES
Long-term debt due within one year	560		485
Notes payable	800		1,451
Accounts payable	1,019		1,017
Customer deposits	344		321
Accrued taxes	72		476
Accrued interest	132		249
Accrued wages	95		92
Fair value of derivative liabilities	64		13
Regulatory liabilities	187		148
Other current liabilities	508		478
TOTAL CURRENT LIABILITIES	3,781		4,730
NONCURRENT LIABILITIES
Provision for injuries and damages	182		195
Pensions and retiree benefits	3,914		1,727
Superfund and other environmental costs	764		749
Asset retirement obligations	188		143
Fair value of derivative liabilities	13		5
Deferred income taxes and investment tax credits	9,076		8,466
Regulatory liabilities	1,993		1,728
Other deferred credits and noncurrent liabilities	181		170
TOTAL NONCURRENT LIABILITIES	16,311		13,183
LONG-TERM DEBT	11,631		10,489
EQUITY
COMMON SHAREHOLDER'S EQUITY (See Statement of Shareholder's Equity)	12,576		12,245
Noncontrolling interest	9
TOTAL EQUITY (See Statement of Equity)	12,585		12,245
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	44,308		40,647
CECONY [Member]
CURRENT ASSETS
Cash and temporary cash investments	645		633
Special deposits	2		86
Accounts receivable - customers, less allowance for uncollectible accounts	1,064		1,123
Other receivables, less allowance for uncollectible accounts	71		127
Accrued unbilled revenue	384		405
Accounts receivable from affiliated companies	132		119
Fuel oil, gas in storage, materials and supplies, at average cost	312		300
Prepayments	126		102
Regulatory assets	132		26
Deferred tax assets - current	94		100
Other current assets	158		55
TOTAL CURRENT ASSETS	3,120		3,076
INVESTMENTS	271		247
UTILITY PLANT AT ORIGINAL COST
General	2,265		2,154
TOTAL	33,584		31,312
Less: Accumulated depreciation	6,970		6,469
Net	26,614		24,843
Construction work in progress	971		1,303
NET UTILITY PLANT	27,585		26,146
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	5		4
NET PLANT	27,590		26,150
OTHER NONCURRENT ASSETS
Goodwill	245		245
Regulatory assets	8,481		6,639
Other deferred charges and noncurrent assets	175		146
TOTAL OTHER NONCURRENT ASSETS	8,656		6,785
TOTAL ASSETS	39,637		36,258
CURRENT LIABILITIES
Long-term debt due within one year	350	[1]	475	[1]
Notes payable	450		1,210
Accounts payable	802		824
Accounts payable to affiliated companies	23		45
Customer deposits	330		308
Accrued taxes	46		46
Accrued taxes to affiliated companies	10		413
Accrued interest	117		139
Accrued wages	84		82
Fair value of derivative liabilities	48		12
Regulatory liabilities	142		107
Other current liabilities	415		385
TOTAL CURRENT LIABILITIES	2,817		4,046
NONCURRENT LIABILITIES
Provision for injuries and damages	176		180
Pensions and retiree benefits	3,493		1,453
Superfund and other environmental costs	666		644
Asset retirement obligations	185		143
Fair value of derivative liabilities	10		3
Deferred income taxes and investment tax credits	8,257		7,832
Regulatory liabilities	1,837		1,598
Other deferred credits and noncurrent liabilities	144		146
TOTAL NONCURRENT LIABILITIES	14,768		11,999
LONG-TERM DEBT	10,864	[1]	9,366	[1]
EQUITY
COMMON SHAREHOLDER'S EQUITY (See Statement of Shareholder's Equity)	11,188		10,847
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	39,637		36,258
Electric Transmission [Member]
UTILITY PLANT AT ORIGINAL COST
Utility plant, at original cost	25,091		23,450
Electric Transmission [Member] | CECONY [Member]
UTILITY PLANT AT ORIGINAL COST
Utility plant, at original cost	23,599		22,073
Gas [Member]
UTILITY PLANT AT ORIGINAL COST
Utility plant, at original cost	6,102		5,494
Gas [Member] | CECONY [Member]
UTILITY PLANT AT ORIGINAL COST
Utility plant, at original cost	5,469		4,891
Steam [Member]
UTILITY PLANT AT ORIGINAL COST
Utility plant, at original cost	2,251		2,194
Steam [Member] | CECONY [Member]
UTILITY PLANT AT ORIGINAL COST
Utility plant, at original cost	$2,251		$2,194
[1]	Rates are to be reset weekly or by auction held every 35 days; December 31, 2014 rates shown.

Consolidated_Balance_Sheet_Par

Consolidated Balance Sheet (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Accounts receivable - customers, allowance for uncollectible accounts	$96	$93
Other receivables, allowance for uncollectible accounts	10	10
Non-utility property, accumulated depreciation	91	90
Intangible assets, accumulated amortization	4	4
CECONY [Member]
Accounts receivable - customers, allowance for uncollectible accounts	90	87
Other receivables, allowance for uncollectible accounts	8	8
Non-utility property, accumulated depreciation	$25	$25

Consolidated_Statement_of_Comm

Consolidated Statement of Common Shareholders' Equity (USD $)	Total	CECONY [Member]	Common Stock [Member]	Common Stock [Member]	Additional Paid-In Capital [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Retained Earnings [Member]	Treasury Stock [Member]	Capital Stock Expense [Member]	Capital Stock Expense [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Noncontrolling Interest [Member]	Repurchased Con Edison Stock [Member]
In Millions, except Share data				CECONY [Member]		CECONY [Member]		CECONY [Member]			CECONY [Member]		CECONY [Member]		CECONY [Member]
BALANCE at Dec. 31, 2011		$10,218		$589		$4,234		$6,429			($64)		($8)		($962)
BALANCE at Dec. 31, 2011	11,436		32		4,991		7,568		-1,033	-64		-58
BALANCE (in shares) at Dec. 31, 2011			292,888,521	235,488,094					23,194,075
Net income for common stock	1,138	1,014					1,138
NET INCOME	1,141	1,017						1,017
Common stock dividends	-709	-682					-709	-682
Issuance of common shares for stock plans, net of repurchases	-1								-4	3
Cumulative preferred dividends	-3	-3						-3
Issuance of common shares for stock plans, net of repurchases (in shares)			-16,625						16,625
Preferred stock redemption		3									3
Other comprehensive income	5	-1										5	-1
BALANCE at Dec. 31, 2012	11,869		32		4,991		7,997		-1,037	-61		-53		0
BALANCE at Dec. 31, 2012		10,552		589		4,234		6,761			-61		-9		-962
BALANCE (in shares) at Dec. 31, 2012			292,871,896	235,488,094					23,210,700
Net income for common stock	1,062	1,020					1,062
NET INCOME	1,062	1,020						1,020
Common stock dividends	-721	-728					-721	-728
Issuance of common shares for stock plans, net of repurchases	7				4				3
Issuance of common shares for stock plans, net of repurchases (in shares)			500						-500
Other comprehensive income	28	3										28	3
BALANCE at Dec. 31, 2013	12,245		32		4,995		8,338		-1,034	-61		-25		0
BALANCE at Dec. 31, 2013	12,245	10,847		589		4,234		7,053			-61		-6		-962
BALANCE (in shares) at Dec. 31, 2013	292,872,396	235,488,094	292,872,396	235,488,094					23,210,200
Net income for common stock	1,092	1,058					1,092
NET INCOME	1,092	1,058						1,058
Common stock dividends	-739	-712					-739	-712
Issuance of common shares for stock plans, net of repurchases	-2				-4				2
Issuance of common shares for stock plans, net of repurchases (in shares)			3,800						-3,800
Other comprehensive income	-20	-5										-20	-5
Noncontrolling interest	9													9
BALANCE at Dec. 31, 2014	12,585		32		4,991		8,691		-1,032	-61		-45		9
BALANCE at Dec. 31, 2014	$12,576	$11,188		$589		$4,234		$7,399			($61)		($11)		($962)
BALANCE (in shares) at Dec. 31, 2014	292,876,196	235,488,094	292,876,196	235,488,094					23,206,400

Schedule_of_Capitalization_Equ

Schedule of Capitalization - Equity (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
Schedule of Capitalization, Equity [Line Items]
TOTAL COMMON SHAREHOLDERS' EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS	$12,621	$12,270
TOTAL COMMON SHAREHOLDERS' EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	292,876,196	292,872,396
Pension plan liability adjustments, net of taxes	-42	-22
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment	-3	-3
TOTAL ACCUMULATED OTHER COMPREHENSIVE LOSS, NET OF TAXES	-45	-25
Common Shareholders' Equity	12,576	12,245
Noncontrolling interest	9
TOTAL EQUITY (See Statement of Equity)	12,585	12,245
CECONY [Member]
Schedule of Capitalization, Equity [Line Items]
TOTAL COMMON SHAREHOLDERS' EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS	11,199	10,853
TOTAL COMMON SHAREHOLDERS' EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	235,488,094	235,488,094
Pension plan liability adjustments, net of taxes	-8	-3
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment	-3	-3
TOTAL ACCUMULATED OTHER COMPREHENSIVE LOSS, NET OF TAXES	-11	-6
Common Shareholders' Equity	11,188	10,847
TOTAL COMMON SHAREHOLDER'S EQUITY (See Statement of Shareholder's Equity)	$11,188	$10,847

Statement_of_Capitalization_Lo

Statement of Capitalization - Long-term Debt (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL DEBENTURES	$10,685		$9,310
TOTAL TRANSITION BONDS	18		22
TOTAL TAX-EXEMPT DEBT	1,130		1,130
Other long-term debt	380		532
Unamortized debt discount	-22		-20
TOTAL	12,191		10,974
Less: Long-term debt due within one year	560		485
TOTAL LONG-TERM DEBT	11,631		10,489
TOTAL	12,191		10,974
TOTAL CAPITALIZATION	24,207		22,734
CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL DEBENTURES	10,150		8,775
TOTAL TAX-EXEMPT DEBT	1,086	[1]	1,086	[1]
Unamortized debt discount	-22	[1]	-20	[1]
TOTAL	11,214	[1]	9,841	[1]
Less: Long-term debt due within one year	350	[1]	475	[1]
TOTAL LONG-TERM DEBT	10,864	[1]	9,366	[1]
TOTAL	11,214	[1]	9,841	[1]
TOTAL CAPITALIZATION	22,052	[1]	20,213	[1]
Debenture Series 2004A, 4.70% Due 2014 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value			200
Interest Rate	4.70%
Maturity Date	2014
Debenture Series 2004A, 4.70% Due 2014 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value			200
Interest Rate	4.70%
Maturity Date	2014
Debenture Series 2009A, 5.55% Due 2014 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value			275
Interest Rate	5.55%
Maturity Date	2014
Debenture Series 2009A, 5.55% Due 2014 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value			275
Interest Rate	5.55%
Maturity Date	2014
Debenture Series 2005A, 5.30% Due 2015 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	40		40
Interest Rate	5.30%
Maturity Date	2015
Debenture Series 2005C, 5.375% Due 2015 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	350		350
Interest Rate	5.38%
Maturity Date	2015
Debenture Series 2005C, 5.375% Due 2015 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	350		350
Interest Rate	5.38%
Maturity Date	2015
Debenture Series 2010A, 2.50% Due 2015 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	55		55
Interest Rate	2.50%
Maturity Date	2015
Debenture Series 2006A, 5.45% Due 2016 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	75		75
Interest Rate	5.45%
Maturity Date	2016
Debenture Series 2006C, 5.50% Due 2016 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	400		400
Interest Rate	5.50%
Maturity Date	2016
Debenture Series 2006C, 5.50% Due 2016 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	400		400
Interest Rate	5.50%
Maturity Date	2016
Debenture Series 2006D, 5.30% Due 2016 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	250		250
Interest Rate	5.30%
Maturity Date	2016
Debenture Series 2006D, 5.30% Due 2016 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	250		250
Interest Rate	5.30%
Maturity Date	2016
Debenture Series 2008A, 5.85% Due 2018 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	600		600
Interest Rate	5.85%
Maturity Date	2018
Debenture Series 2008A, 5.85% Due 2018 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	600		600
Interest Rate	5.85%
Maturity Date	2018
Debenture Series 2008A, 6.15% Due 2018 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	50		50
Interest Rate	6.15%
Maturity Date	2018
Debenture Series 2008C, 7.125% Due 2018 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	600		600
Interest Rate	7.13%
Maturity Date	2018
Debenture Series 2008C, 7.125% Due 2018 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	600		600
Interest Rate	7.13%
Maturity Date	2018
Debenture Series 2009A, 4.96% Due 2019 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	60		60
Interest Rate	4.96%
Maturity Date	2019
Debenture Series 2009B, 6.65% Due 2019 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	475		475
Interest Rate	6.65%
Maturity Date	2019
Debenture Series 2009B, 6.65% Due 2019 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	475		475
Interest Rate	6.65%
Maturity Date	2019
Debenture Series 2010A, 4.45% Due 2020 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	350		350
Interest Rate	4.45%
Maturity Date	2020
Debenture Series 2010A, 4.45% Due 2020 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	350		350
Interest Rate	4.45%
Maturity Date	2020
Debenture Series 2014B, 3.30% Due 2024 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	250
Interest Rate	3.30%
Maturity Date	2024
Debenture Series 2014B, 3.30% Due 2024 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	250
Interest Rate	3.30%
Maturity Date	2024
Debenture Series 1997F, 6.50% Due 2027 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	80		80
Interest Rate	6.50%
Maturity Date	2027
Debenture Series 2003A, 5.875% Due 2033 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	175		175
Interest Rate	5.88%
Maturity Date	2033
Debenture Series 2003A, 5.875% Due 2033 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	175		175
Interest Rate	5.88%
Maturity Date	2033
Debenture Series 2003C, 5.10% Due 2033 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	200		200
Interest Rate	5.10%
Maturity Date	2033
Debenture Series 2003C, 5.10% Due 2033 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	200		200
Interest Rate	5.10%
Maturity Date	2033
Debenture Series 2004B, 5.70% Due 2034 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	200		200
Interest Rate	5.70%
Maturity Date	2034
Debenture Series 2004B, 5.70% Due 2034 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	200		200
Interest Rate	5.70%
Maturity Date	2034
Debenture Series 2005A, 5.30% Due 2035 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	350		350
Interest Rate	5.30%
Maturity Date	2035
Debenture Series 2005A, 5.30% Due 2035 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	350		350
Interest Rate	5.30%
Maturity Date	2035
Debenture Series 2005B, 5.25% Due 2035 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	125		125
Interest Rate	5.25%
Maturity Date	2035
Debenture Series 2005B, 5.25% Due 2035 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	125		125
Interest Rate	5.25%
Maturity Date	2035
Debenture Series 2006A, 5.85% Due 2036 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	400		400
Interest Rate	5.85%
Maturity Date	2036
Debenture Series 2006A, 5.85% Due 2036 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	400		400
Interest Rate	5.85%
Maturity Date	2036
Debenture Series 2006B, 6.20% Due 2036 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	400		400
Interest Rate	6.20%
Maturity Date	2036
Debenture Series 2006B, 6.20% Due 2036 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	400		400
Interest Rate	6.20%
Maturity Date	2036
Debenture Series 2006E, 5.70% Due 2036 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	250		250
Interest Rate	5.70%
Maturity Date	2036
Debenture Series 2006E, 5.70% Due 2036 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	250		250
Interest Rate	5.70%
Maturity Date	2036
Debenture Series 2007A, 6.30% Due 2037 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	525		525
Interest Rate	6.30%
Maturity Date	2037
Debenture Series 2007A, 6.30% Due 2037 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	525		525
Interest Rate	6.30%
Maturity Date	2037
Debenture Series 2008B, 6.75% Due 2038 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	600		600
Interest Rate	6.75%
Maturity Date	2038
Debenture Series 2008B, 6.75% Due 2038 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	600		600
Interest Rate	6.75%
Maturity Date	2038
Debenture Series 2009B, 6.00% Due 2039 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	60		60
Interest Rate	6.00%
Maturity Date	2039
Debenture Series 2009C, 5.50% Due 2039 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	600		600
Interest Rate	5.50%
Maturity Date	2039
Debenture Series 2009C, 5.50% Due 2039 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	600		600
Interest Rate	5.50%
Maturity Date	2039
Debenture Series 2010B, 5.70% Due 2040 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	350		350
Interest Rate	5.70%
Maturity Date	2040
Debenture Series 2010B, 5.70% Due 2040 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	350		350
Interest Rate	5.70%
Maturity Date	2040
Debenture Series 2010B, 5.50% Due 2040 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	115		115
Interest Rate	5.50%
Maturity Date	2040
Debenture Series 2012A, 4.20% Due 2042 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	400		400
Interest Rate	4.20%
Maturity Date	2042
Debenture Series 2012A, 4.20% Due 2042 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	400		400
Interest Rate	4.20%
Maturity Date	2042
Debenture Series Two Thousand Thirteena Three Point Nine Five Percent Due Two Thousand Forty Three [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	700		700
Interest Rate	3.95%
Maturity Date	2043
Debenture Series Two Thousand Thirteena Three Point Nine Five Percent Due Two Thousand Forty Three [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	700		700
Interest Rate	3.95%
Maturity Date	2043
Debenture Series 2014A, 4.45% Due 2044 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	850
Interest Rate	4.45%
Maturity Date	2044
Debenture Series 2014A, 4.45% Due 2044 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	850
Interest Rate	4.45%
Maturity Date	2044
Debenture Series 2014C, 4.625% Due 2054 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	750
Interest Rate	4.63%
Maturity Date	2054
Debenture Series 2014C, 4.625% Due 2054 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	750
Interest Rate	4.63%
Maturity Date	2054
Debenture Series 2004-1, 5.22% Due 2019 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	18	[2]	22	[2]
Interest Rate	5.22%	[2]
Maturity Date	2019	[2]
Debenture Series 1995, 0.06% Due 2015 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	44	[1]	44	[1]
Interest Rate	0.06%	[1]
Maturity Date	2015	[1]
Tax Exempt Debt Series 2004B-1, 0.13% Due 2032 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	127	[1]	127	[1]
Interest Rate	0.13%	[1]
Maturity Date	2032	[1]
Tax Exempt Debt Series 2004B-1, 0.13% Due 2032 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	127	[1]	127	[1]
Interest Rate	0.13%	[1]
Maturity Date	2032	[1]
Tax-Exempt Debt Series 1999A, 0.14% Due 2034 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	293	[1]	293	[1]
Interest Rate	0.14%	[1]
Maturity Date	2034	[1]
Tax-Exempt Debt Series 1999A, 0.14% Due 2034 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	293	[1]	293	[1]
Interest Rate	0.14%	[1]
Maturity Date	2034	[1]
Tax Exempt Debt Series 2004B-2, 0.14% Due 2035 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	20	[1]	20	[1]
Interest Rate	0.14%	[1]
Maturity Date	2035	[1]
Tax Exempt Debt Series 2004B-2, 0.14% Due 2035 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	20	[1]	20	[1]
Interest Rate	0.14%	[1]
Maturity Date	2035	[1]
Tax-Exempt Debt Series 2001B, 0.11% Due 2036 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	98	[1]	98	[1]
Interest Rate	0.11%	[1]
Maturity Date	2036	[1]
Tax-Exempt Debt Series 2001B, 0.11% Due 2036 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	98	[1]	98	[1]
Interest Rate	0.11%	[1]
Maturity Date	2036	[1]
Tax-Exempt Debt Series 2010A, 0.03% Due 2036 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	225	[1]	225	[1]
Interest Rate	0.03%	[1]
Maturity Date	2036	[1]
Tax-Exempt Debt Series 2010A, 0.03% Due 2036 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	225	[1]	225	[1]
Interest Rate	0.03%	[1]
Maturity Date	2036	[1]
Tax-Exempt Debt Series 2004A, 0.10% Due 2039 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	98	[1]	98	[1]
Interest Rate	0.10%	[1]
Maturity Date	2039	[1]
Tax-Exempt Debt Series 2004A, 0.10% Due 2039 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	98	[1]	98	[1]
Interest Rate	0.10%	[1]
Maturity Date	2039	[1]
Tax-Exempt Debt Series 2004C, 0.04% Due 2039 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	99	[1]	99	[1]
Interest Rate	0.04%	[1]
Maturity Date	2039	[1]
Tax-Exempt Debt Series 2004C, 0.04% Due 2039 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	99	[1]	99	[1]
Interest Rate	0.04%	[1]
Maturity Date	2039	[1]
Tax-Exempt Debt Series 2005A, 0.03% Due 2039 [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	126	[1]	126	[1]
Interest Rate	0.03%	[1]
Maturity Date	2039	[1]
Tax-Exempt Debt Series 2005A, 0.03% Due 2039 [Member] | CECONY [Member]
Schedule of Capitalization, Long-term Debt [Line Items]
Debt Instrument, Fair Value	$126	[1]	$126	[1]
Interest Rate	0.03%	[1]
Maturity Date	2039	[1]
[1]	Rates are to be reset weekly or by auction held every 35 days; December 31, 2014 rates shown.
[2]	The final date to pay the entire remaining unpaid principal balance, if any, of all outstanding bonds is May 17, 2021.

General

General	12 Months Ended
	Dec. 31, 2014
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 Con Edison’s other utility subsidiary, Orange and Rockland Utilities, Inc. (O&R), and Con Edison’s competitive energy businesses (discussed below) 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 subsidiaries, provides electric service in southeastern New York and adjacent areas of northern New Jersey and eastern Pennsylvania and gas service in southeastern New York and adjacent areas of eastern Pennsylvania. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company which sells to retail customers electricity purchased in wholesale markets and enters into related hedging transactions and also provides energy-related products and services to retail customers; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects. In addition, in 2014 Con Edison formed Consolidated Edison Transmission LLC (Con Edison Transmission) to invest in a transmission company. See information about Con Edison Transmission under “Guarantees” in Note H.
CECONY [Member]
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 Con Edison’s other utility subsidiary, Orange and Rockland Utilities, Inc. (O&R), and Con Edison’s competitive energy businesses (discussed below) 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 subsidiaries, provides electric service in southeastern New York and adjacent areas of northern New Jersey and eastern Pennsylvania and gas service in southeastern New York and adjacent areas of eastern Pennsylvania. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company which sells to retail customers electricity purchased in wholesale markets and enters into related hedging transactions and also provides energy-related products and services to retail customers; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects. In addition, in 2014 Con Edison formed Consolidated Edison Transmission LLC (Con Edison Transmission) to invest in a transmission company. See information about Con Edison Transmission under “Guarantees” in Note H.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Summary of Significant Accounting Policies	Note A – Summary of Significant Accounting Policies
	Principles of Consolidation
	The Companies’ consolidated financial statements include the accounts of their respective majority-owned subsidiaries, and variable interest entities (see Note Q), as required. All intercompany balances and 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. The Utilities are receiving or being credited with a return on all of their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on all of their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable state regulators.
	Other significant accounting policies of the Companies are referenced below in this Note A and in the notes that follow.
	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 R.
	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 1.6 percent, 4.0 percent and 6.5 percent for 2014, 2013 and 2012, respectively. The AFUDC rates for O&R were 2.6 percent, 5.7 percent and 7.0 percent for 2014, 2013 and 2012, 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 3.1 percent, 3.2 percent and 3.1 percent for 2014, 2013 and 2012, respectively. The average depreciation rates for O&R were 2.9 percent, 2.8 percent and 2.9 percent for 2014, 2013 and 2012, respectively.
	The estimated lives for utility plant for CECONY range from 5 to 85 years for electric and 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, 2014 and 2013, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:
			Con Edison						CECONY
	(Millions of Dollars)		2014			2013			2014		2013
	Electric
	Generation		$	451		$	452		$	451	$	452
	Transmission			2,956			2,776			2,744		2,597
	Distribution			16,361			15,277			15,531		14,496
	Gas*			5,006			4,469			4,530		4,013
	Steam			1,795			1,790			1,795		1,790
	General			1,650			1,565			1,498		1,433
	Held for future use			76			73			65		62
	Construction work in progress			1,031			1,393			971		1,303
	Net Utility Plant		$	29,326		$	27,795		$	27,585	$	26,146
	*	Primarily distribution.
	Under the Utilities’ rate plans, the aggregate annual depreciation allowance in effect at December 31, 2014 was $1,048 million, including $993 million under CECONY’s electric, gas and steam rate plans that have been approved by the New York State Public Service Commission (NYSPSC).
	Non-Utility Plant
	Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the competitive energy businesses’ renewable electric production and gas storage. 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 range from 3 to 30 years.
	Goodwill
	Con Edison tests goodwill for impairment at least annually. Goodwill is tested for impairment using a two-step approach. The first step of the 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, the second step is performed to measure the amount of impairment loss, if any. The second step requires a calculation of the implied fair value of goodwill. See Note K.
	Impairments
	Con Edison evaluates the impairment of long-lived assets, based on projections of undiscounted future cash flows, whenever events or changes in circumstances indicate that the carrying amounts of such assets may not be recoverable. In the event an evaluation indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are written down to their estimated fair value. No impairment charges were recognized in 2014, 2013 or 2012.
	Revenues
	The Utilities and Con Edison Solutions recognize revenues for energy service on a monthly billing cycle basis. 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 Utilities and Con Edison Solutions accrue revenues at the end of each month for estimated energy service not yet billed to customers.
	CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism 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)		2014			2013			2012
	Con Edison		$	365		$	354		$	334
	CECONY			343			329			306
	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 or two months). For the Utilities’ gas costs, differences between actual and billed gas costs during the 12-month period ending each August are charged or refunded to customers during a subsequent 12-month period.
	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
	Investments consist primarily of the investments of Con Edison’s competitive energy businesses, which are accounted for under the equity method (depending on the subsidiaries’ percentage ownership). Utilities’ investments are recorded at fair value and include the investments of the deferred income plan and the supplemental retirement income plan in trust-owned life insurance assets.
	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 (OCI), net of tax. Such amounts will be adjusted as they are subsequently recognized as components of net 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 net 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. Generally, O&R also defers such difference pursuant to its rate plans. See Note B – Regulatory Matters.
	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 the accounting rules for income taxes, the Companies have recorded an accumulated deferred federal income tax liability for temporary differences between the book and tax basis of assets and liabilities at current tax rates. 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 tax liability, in accordance with the accounting rules for regulated operations, the Utilities have established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense. See Notes B and L. In 1993, the NYSPSC issued a Policy Statement approving accounting procedures consistent with the accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. See 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 tax sharing agreements among the members of the consolidated group. Tax loss 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
Generally research and development costs are charged to operating expenses as incurred. Research and development costs were as follows:
		For the Years Ended December 31,
(Millions of Dollars)		2014			2013			2012
Con Edison		$	22		$	18		$	21
CECONY			20			16			19
Reclassification
Certain prior year amounts have been reclassified to conform with the current year presentation.
Earnings Per Common Share
Con Edison presents basic and diluted earnings per share on the face of its consolidated income statement. Basic earnings per share (EPS) are calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.
Potentially dilutive securities for Con Edison consist of restricted stock units, deferred stock units and stock options for which the average market price of the common shares for the period was greater than the exercise price. See Note M.
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)		2014			2013			2012
Net income for common stock		$	1,092		$	1,062		$	1,138
Weighted average common shares outstanding – Basic			292.9			292.9			292.9
Add: Incremental shares attributable to effect of potentially dilutive securities			1.1			1.5			1.6
Adjusted weighted average common shares outstanding – Diluted			294			294.4			294.5
Net Income for common stock per common share – basic		$	3.73		$	3.62		$	3.88
Net Income for common stock per common share – diluted		$	3.71		$	3.61		$	3.86
The computation of diluted EPS for the years ended December 31, 2014, 2013 and 2012 exclude immaterial amounts of performance share awards that were not included because of their anti-dilutive effect.
Estimates
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Changes in Accumulated Other Comprehensive Income by Component
Changes to accumulated other comprehensive income (OCI) for Con Edison and CECONY are as follows:
(Millions of Dollars)		Con Edison			CECONY
Accumulated OCI, net of taxes, at December 31, 2012		$	(53	)	$	(9	)
OCI before reclassifications, net of tax of $(15) and $(1) for Con Edison and CECONY, respectively			21			2
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(5) and $(1) for Con Edison and CECONY, respectively(a)(b)			7			1
Total OCI, net of taxes, at December 31, 2013			28			3
Accumulated OCI, net of taxes, at December 31, 2013(b)		$	(25	)	$	(6	)
OCI before reclassifications, net of tax of $18 and $4 for Con Edison and CECONY, respectively			(26	)		(6	)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(4) and $(1) for Con Edison and CECONY, respectively(a)(b)			6			1
Total OCI, net of taxes, at December 31, 2014			(20	)		(5	)
Accumulated OCI, net of taxes, at December 31, 2014(b)		$	(45	)	($	11	)
(a)	For the portion of unrecognized pension and other postretirement benefit costs relating to the regulated Utilities, costs are recorded into, and amortized out of, regulatory assets instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of net periodic pension and other postretirement benefit cost. See Notes E and F.
(b)	Tax reclassified from accumulated OCI is reported in the income tax expense line item of the income statement.
CECONY [Member]
Summary of Significant Accounting Policies	Note A – Summary of Significant Accounting Policies
	Principles of Consolidation
	The Companies’ consolidated financial statements include the accounts of their respective majority-owned subsidiaries, and variable interest entities (see Note Q), as required. All intercompany balances and 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. The Utilities are receiving or being credited with a return on all of their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on all of their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable state regulators.
	Other significant accounting policies of the Companies are referenced below in this Note A and in the notes that follow.
	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 R.
	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 1.6 percent, 4.0 percent and 6.5 percent for 2014, 2013 and 2012, respectively. The AFUDC rates for O&R were 2.6 percent, 5.7 percent and 7.0 percent for 2014, 2013 and 2012, 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 3.1 percent, 3.2 percent and 3.1 percent for 2014, 2013 and 2012, respectively. The average depreciation rates for O&R were 2.9 percent, 2.8 percent and 2.9 percent for 2014, 2013 and 2012, respectively.
	The estimated lives for utility plant for CECONY range from 5 to 85 years for electric and 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, 2014 and 2013, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:
			Con Edison						CECONY
	(Millions of Dollars)		2014			2013			2014		2013
	Electric
	Generation		$	451		$	452		$	451	$	452
	Transmission			2,956			2,776			2,744		2,597
	Distribution			16,361			15,277			15,531		14,496
	Gas*			5,006			4,469			4,530		4,013
	Steam			1,795			1,790			1,795		1,790
	General			1,650			1,565			1,498		1,433
	Held for future use			76			73			65		62
	Construction work in progress			1,031			1,393			971		1,303
	Net Utility Plant		$	29,326		$	27,795		$	27,585	$	26,146
	*	Primarily distribution.
	Under the Utilities’ rate plans, the aggregate annual depreciation allowance in effect at December 31, 2014 was $1,048 million, including $993 million under CECONY’s electric, gas and steam rate plans that have been approved by the New York State Public Service Commission (NYSPSC).
	Non-Utility Plant
	Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the competitive energy businesses’ renewable electric production and gas storage. 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 range from 3 to 30 years.
	Goodwill
	Con Edison tests goodwill for impairment at least annually. Goodwill is tested for impairment using a two-step approach. The first step of the 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, the second step is performed to measure the amount of impairment loss, if any. The second step requires a calculation of the implied fair value of goodwill. See Note K.
	Impairments
	Con Edison evaluates the impairment of long-lived assets, based on projections of undiscounted future cash flows, whenever events or changes in circumstances indicate that the carrying amounts of such assets may not be recoverable. In the event an evaluation indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are written down to their estimated fair value. No impairment charges were recognized in 2014, 2013 or 2012.
	Revenues
	The Utilities and Con Edison Solutions recognize revenues for energy service on a monthly billing cycle basis. 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 Utilities and Con Edison Solutions accrue revenues at the end of each month for estimated energy service not yet billed to customers.
	CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism 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)		2014			2013			2012
	Con Edison		$	365		$	354		$	334
	CECONY			343			329			306
	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 or two months). For the Utilities’ gas costs, differences between actual and billed gas costs during the 12-month period ending each August are charged or refunded to customers during a subsequent 12-month period.
	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
	Investments consist primarily of the investments of Con Edison’s competitive energy businesses, which are accounted for under the equity method (depending on the subsidiaries’ percentage ownership). Utilities’ investments are recorded at fair value and include the investments of the deferred income plan and the supplemental retirement income plan in trust-owned life insurance assets.
	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 (OCI), net of tax. Such amounts will be adjusted as they are subsequently recognized as components of net 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 net 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. Generally, O&R also defers such difference pursuant to its rate plans. See Note B – Regulatory Matters.
	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 the accounting rules for income taxes, the Companies have recorded an accumulated deferred federal income tax liability for temporary differences between the book and tax basis of assets and liabilities at current tax rates. 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 tax liability, in accordance with the accounting rules for regulated operations, the Utilities have established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense. See Notes B and L. In 1993, the NYSPSC issued a Policy Statement approving accounting procedures consistent with the accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. See 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 tax sharing agreements among the members of the consolidated group. Tax loss 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
Generally research and development costs are charged to operating expenses as incurred. Research and development costs were as follows:
		For the Years Ended December 31,
(Millions of Dollars)		2014			2013			2012
Con Edison		$	22		$	18		$	21
CECONY			20			16			19
Reclassification
Certain prior year amounts have been reclassified to conform with the current year presentation.
Earnings Per Common Share
Con Edison presents basic and diluted earnings per share on the face of its consolidated income statement. Basic earnings per share (EPS) are calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.
Potentially dilutive securities for Con Edison consist of restricted stock units, deferred stock units and stock options for which the average market price of the common shares for the period was greater than the exercise price. See Note M.
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)		2014			2013			2012
Net income for common stock		$	1,092		$	1,062		$	1,138
Weighted average common shares outstanding – Basic			292.9			292.9			292.9
Add: Incremental shares attributable to effect of potentially dilutive securities			1.1			1.5			1.6
Adjusted weighted average common shares outstanding – Diluted			294			294.4			294.5
Net Income for common stock per common share – basic		$	3.73		$	3.62		$	3.88
Net Income for common stock per common share – diluted		$	3.71		$	3.61		$	3.86
The computation of diluted EPS for the years ended December 31, 2014, 2013 and 2012 exclude immaterial amounts of performance share awards that were not included because of their anti-dilutive effect.
Estimates
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Changes in Accumulated Other Comprehensive Income by Component
Changes to accumulated other comprehensive income (OCI) for Con Edison and CECONY are as follows:
(Millions of Dollars)		Con Edison			CECONY
Accumulated OCI, net of taxes, at December 31, 2012		$	(53	)	$	(9	)
OCI before reclassifications, net of tax of $(15) and $(1) for Con Edison and CECONY, respectively			21			2
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(5) and $(1) for Con Edison and CECONY, respectively(a)(b)			7			1
Total OCI, net of taxes, at December 31, 2013			28			3
Accumulated OCI, net of taxes, at December 31, 2013(b)		$	(25	)	$	(6	)
OCI before reclassifications, net of tax of $18 and $4 for Con Edison and CECONY, respectively			(26	)		(6	)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(4) and $(1) for Con Edison and CECONY, respectively(a)(b)			6			1
Total OCI, net of taxes, at December 31, 2014			(20	)		(5	)
Accumulated OCI, net of taxes, at December 31, 2014(b)		$	(45	)	($	11	)
(a)	For the portion of unrecognized pension and other postretirement benefit costs relating to the regulated Utilities, costs are recorded into, and amortized out of, regulatory assets instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of net periodic pension and other postretirement benefit cost. See Notes E and F.
(b)	Tax reclassified from accumulated OCI is reported in the income tax expense line item of the income statement.

Regulatory_Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2014
Regulatory Matters	Note B – 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 O&R’s New Jersey and Pennsylvania regulated utility subsidiaries are approved by utility regulators in those states. 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’ 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. Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases for items such as major storm events 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.
	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.
	Rate base is, in general, the sum of the Utilities’ net plant and working capital less deferred taxes. 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”). The New Jersey Board of Public Utilities (NJBPU) and the Pennsylvania Public Utility Commission (PAPUC) use the rate base balances that would exist at the beginning of the 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 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 is determined by multiplying the Utilities’ rate base by the utility’s 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		April 2010 – December 2013		January 2014 – December 2015
	Base rate changes(a)		Yr. 1 – $420 million		Yr. 1 – $(76.2) million(c)
			Yr. 2 – $420 million		Yr. 2 – $124.0 million(c)
			Yr. 3 – $287 million(b)
	Amortizations to income of net		$(75.3) million over three years		$(37) million over two years, that includes $107 million annually for deferred major storm costs
	regulatory (assets) and liabilities
	Other revenue sources		Retention of $120 million of annual transmission congestion revenues from the sale of transmission rights ($90 million for the period April 1, 2013 to December 31, 2013).		Retention of $90 million of annual transmission congestion revenues.
	Revenue decoupling mechanisms		In 2012 and 2013, the company deferred for customer benefit $59 million and $34 million of revenues, respectively.		In 2014, the company deferred for customer benefit $146 million of revenues.
	Recoverable energy costs		Current rate recovery of purchased power and fuel costs.		Continuation of current rate recovery of purchased power and fuel costs(d).
	Negative revenue adjustments		Potential penalties (up to $350 million annually) if certain performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.		Potential penalties (up to $400 million annually) if certain performance targets are not met. In 2014, the company recorded a $5 million negative revenue adjustment.
	Cost reconciliations(e)		In 2012 and 2013, the company deferred $146 million of net regulatory liabilities and $35 million of net regulatory assets, respectively.		In 2014, the company deferred $57 million of net regulatory liabilities.
	Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
			Transmission and distribution: Yr. 1 –$13,818 million; Yr. 2 – $14,742 million;		Transmission and distribution: Yr. 1 – $16,869 million; Yr. 2 – $17,401 million
			Yr. 3 – $15,414 million		Storm hardening: Yr. 1 – $89 million; Yr. 2 – $177 million
			Enterprise resource project: Yr. 2 – $25 million;		Other: Yr. 1 – $2,034 million; Yr. 2 – $2,102 million
			Yr. 3 -$115 million		The company deferred an immaterial amount as a regulatory liability in 2014.
			Other: Yr. 1 – $1,487 million;
			Yr. 2 – $1,565 million; Yr. 3 – $1,650 million
			The company deferred an immaterial amount and $7 million as a regulatory liability in 2012 and 2013, respectively.
	Average rate base		Yr. 1 – $14,887 million		Yr. 1 – $17,323 million
			Yr. 2 – $15,987 million		Yr. 2 – $18,113 million
			Yr. 3 – $16,826 million
	Weighted average cost of capital (after-tax)		7.76 percent		Yr. 1 – 7.05 percent
					Yr. 2 – 7.08 percent
	Authorized return on common equity		10.15 percent assuming the company achieved austerity measures of $27 million, $20 million and $13 million for Yrs. 1, 2 and 3. Austerity measures were achieved.		9.2 percent
	Earnings sharing		Actual earnings above an annual earnings threshold of 11.15 percent for Yr. 1 and 10.65 percent for Yrs. 2 and 3 were to be applied to reduce regulatory assets for pensions and other postretirement benefits and other costs.		Most earnings above an annual earnings threshold of 9.8 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 $17.5 million above the threshold for the period ended 2013.
	Cost of long-term debt		5.65 percent		Yr. 1 – 5.17 percent
					Yr. 2 – 5.23 percent
	Common equity ratio		48 percent		48 percent
	(a)	$249 million of annual revenues collected from electric customers is subject to potential refund following NYSPSC staff review of costs. See “Other Regulatory Matters” below in this Note B. Revenues for each of 2014 and 2015 include $21 million as funding for major storm reserve.
	(b)	Temporary portion of the increase ($134 million) that was scheduled to go into effect April 1, 2012 was eliminated by the application of available credits.
	(c)	The impact of these base rate changes is being deferred which will result in a $30 million regulatory liability at December 31, 2015.
	(d)	With respect to transmission service provided pursuant to the open access transmission tariff of PJM Interconnection L.L.C. (PJM), the company recovered in 2014 part of charges incurred during 2013 (approximately $20 million) and, commencing in January 2014 and unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. In January 2014, PJM submitted to FERC a request that would substantially increase the charges for the transmission service. CECONY has opposed this increase.
	(e)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.
	In January 2015, CECONY filed a request with the NYSPSC for an electric rate increase of $368 million, effective January 2016. The filing reflects a return on common equity of 10 percent and a common equity ratio of approximately 48 percent.
	The company also is requesting continuation of provisions pursuant to which expenses for pension and other postretirement benefits, variable rate, tax-exempt debt, storms, the impact of new laws and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is requesting reconciliation of property taxes and municipal infrastructure support costs that, unlike the current provisions, would provide for full reconciliation of such costs. The filing also reflects continuation of the revenue decoupling mechanism and provisions for recovery of purchased power and fuel costs from customers.
	CECONY – Gas
	Effective period		October 2010 – December 2013		January 2014 – December 2016
	Base rate changes(a)		Yr. 1 – $47 million		Yr. 1 – $(54.6) million(b)
			Yr. 2 – $48 million		Yr. 2 – $38.6 million(b)
			Yr. 3 – $47 million		Yr. 3 – $56.8 million(b)
	Amortizations to income of net		$(53.1) million over three years		$4 million over three years
	regulatory (assets) and liabilities
	Other revenue sources		Retention of revenues from non-firm customers of up to $58 million and 25 percent of any such revenues above $58 million. The company retained $57 million and $64 million of such revenues in 2012 and 2013, respectively.		Retention of revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. The company retained $70 million of such revenues in 2014.
	Revenue decoupling mechanisms		In 2012 and 2013, the company deferred $22 million and $36 million of regulatory liabilities, respectively.		In 2014, the company deferred $28 million of regulatory liabilities.
	Recoverable energy costs		Current rate recovery of purchased gas costs.		Continuation of current rate recovery of purchased gas costs.
	Negative revenue adjustments		Potential penalties (up to $12.6 million annually)		Potential penalties (up to $33 million in 2014, $44 million in 2015, and $56 million in 2016) if certain gas performance targets are not met. In 2014, the company did not record any negative revenue adjustments.
			if certain gas customer service and system performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.
	Cost reconciliations(c)		In 2012 and 2013, the company deferred $9 million and $26 million of net regulatory assets, respectively.		In 2014, the company deferred $38 million of net regulatory liabilities.
Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
		Gas delivery Yr. 1 – $2,934 million;		Gas delivery Yr. 1 – $3,899 million;
		Yr. 2 – $3,148 million; Yr. 3 – $3,346 million		Yr. 2 – $4,258 million; Yr. 3 – $4,698 million
		For 2012 and 2013, $2.9 million and $9.5 million were deferred as a regulatory liability respectively.		Storm hardening: Yr. 1 – $3 million;
				Yr. 2 – $8 million; Yr. 3 – $30 million
				There were no deferrals recorded in 2014.
Average rate base		Yr. 1 – $3,027 million		Yr. 1 – $3,521 million
		Yr. 2 – $3,245 million		Yr. 2 – $3,863 million
		Yr. 3 – $3,434 million		Yr. 3 – $4,236 million
Weighted average cost of capital		7.46 percent		Yr. 1 – 7.10 percent
(after-tax)				Yr. 2 – 7.13 percent
				Yr. 3 – 7.21 percent
Authorized return on common equity		9.6 percent assuming the company achieved unspecified austerity measures of $4 million and $2 million in 2012 and 2013. Austerity measures were achieved.		9.3 percent
Earnings sharing		Actual earnings did not exceed the thresholds of 10.35 percent in Yr. 1 and 10.15 percent in Yrs. 2 and 3.		Most 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.
Cost of long-term debt		5.57 percent		Yr. 1 – 5.17 percent
				Yr. 2 – 5.23 percent
				Yr. 3 – 5.39 percent
Common equity ratio		48 percent		48 percent
(a)	$32 million of annual revenues collected from gas customers is subject to potential refund. See “Other Regulatory Matters” below.
(b)	The impact of these base rate changes is being deferred which will result in a $32 million regulatory liability at December 31, 2016.
(c)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.
CECONY – Steam
Effective period		October 2010 – December 2013		January 2014 – December 2016
Base rate changes(a)		Yr. 1 – $49.5 million		Yr. 1 – $(22.4) million(b)
		Yr. 2 – $49.5 million		Yr. 2 – $19.8 million(b)
		Yr. 3 – $17.8 million		Yr. 3 – $20.3 million(b)
		Yr. 3 – $31.7 million collected through a surcharge
Amortizations to income of net		$(20.1) million over three years		$37 million over three years
regulatory (assets) and liabilities
Recoverable energy costs		Current rate recovery of purchased power and fuel costs.		Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments		Potential penalties (up to $1 million annually) if certain steam performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.		Potential penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014, the company did not record any negative revenue adjustments.
Cost reconciliations(c)		In 2012 and 2013, the company deferred $12 million and $17 million of net regulatory liabilities, respectively.		In 2014, the company deferred $42 million of net regulatory liabilities.
Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
		Production Yr. 1 – $415 million;		Production Yr. 1 – $1,752 million;
		Yr. 2 – $426 million; Yr. 3 – $433 million		Yr. 2 – $1,732 million; Yr. 3 – $1,720 million
		Distribution: Yr. 1 – $521 million; Yr. 2 – $534 million; Yr. 3 – $543 million		Distribution: Yr. 1 – $6 million; Yr. 2 – $11 million; Yr. 3 – $25 million
		The company reduced its regulatory liability by $0.2 million in 2012 and made no deferral in 2013.		The company reduced its regulatory liability by $1.1 million in 2014.
Average rate base		Yr. 1 – $1,589 million		Yr. 1 – $1,511 million
		Yr. 2 – $1,603 million		Yr. 2 – $1,547 million
		Yr. 3 – $1,613 million		Yr. 3 – $1,604 million
Weighted average cost of		7.46 percent		Yr. 1 – 7.10 percent
capital (after-tax)				Yr. 2 – 7.13 percent
				Yr. 3 – 7.21 percent
Authorized return on common equity		9.6 percent (assuming company achieved unspecified austerity measures of $3 million and $2 million in 2012 and 2013). Austerity measures were achieved.		9.3 percent
Earnings sharing		Weather normalized earnings did not exceed the threshold of 10.35 percent in Yr. 1 and 10.15 percent in Yrs. 2 and 3. In 2013, actual earnings were $0.5 million above the earnings threshold of 10.15 percent.		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.
Cost of long-term debt		5.57 percent		Yr. 1 – 5.17 percent
				Yr. 2 – 5.23 percent
				Yr. 3 – 5.39 percent
Common equity ratio		48 percent		48 percent
(a)	$6 million of annual revenues collected from steam customers is subject to potential refund. See “Other Regulatory Matters” below in this Note B.
(b)	The impact of these base rate changes is being deferred which will result in an $8 million regulatory liability at December 31, 2016.
(c)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.
O&R New York – Electric
Effective period		July 2012 – June 2015
Base rate changes		Yr. 1 – $19.4 million
		Yr. 2 – $8.8 million
		Yr. 3 – $15.2 million
Amortizations to income of net		$(32.2) million over three years
regulatory (assets) and liabilities
Revenue decoupling mechanisms		In 2012, 2013 and 2014, the company deferred for the customer’s benefit $2.6 million, $3.2 million and ($3.4) million.
Recoverable energy costs		Current rate recovery of purchased power and fuel costs.
Negative revenue adjustments		Potential penalties (up to $3 million annually) if certain customer service and system reliability performance targets are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.
Cost reconciliations		In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase to regulatory assets, respectively.
Net utility plant reconciliations		Target levels reflected in rates were:
		Yr. 1 – $678 million; Yr. 2- $704 million; Yr. 3 – $753 million
		The company increased its regulatory liability by $4.2 million in 2012. The company reduced its regulatory, liability by $1.1 million and $2.3 million in 2013 and 2014, respectively.
Average rate base		Yr. 1 – $671 million
		Yr. 2 – $708 million
		Yr. 3 – $759 million
Weighted average cost of capital (after-tax)		Yr. 1 – 7.61 percent
		Yr. 2 – 7.65 percent
		Yr. 3 – 7.48 percent
Authorized return on common equity		Yr. 1 – 9.4 percent
		Yr. 2 – 9.5 percent
		Yr. 3 – 9.6 percent
Earnings sharing		The company recorded a regulatory liability of $1 million for earnings above the sharing threshold under the rate plan as of December 31, 2014.
Cost of long-term debt		Yr. 1 – 6.07 percent
		Yr. 2 – 6.07 percent
		Yr. 3 – 5.64 percent
Common equity ratio		48 percent
On November 14, 2014, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective November 1, 2015, of $33.4 million. The filing reflects a return on common equity of 9.75 percent and a common equity ratio of 48 percent. The filing proposes continuation of the current 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 2009 – December 2014
Base rate changes		Yr. 1 – $9 million
		Yr. 2 – $9 million
		Yr. 3 – $4.6 million
		Yr. 3 – $4.3 million collected through a surcharge
Amortization to income of net regulatory (assets) and liabilities		$(2) million over three years
Revenue decoupling mechanisms		In 2012, 2013 and 2014, the company deferred $4.7 million, $0.7 million and $(0.1) million of regulatory liabilities, respectively.
Recoverable energy costs		Current rate recovery of purchased gas costs.
Negative revenue adjustments		Potential penalties (up to $1.4 million annually) if certain operations and customer service requirements are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.
Cost reconciliations		In 2012, 2013 and 2014, the company deferred $0.7 million, $8.3 million and $8.3 million as net regulatory assets, respectively.
Net utility plant reconciliations		The company deferred $0.7 million in 2012 as a regulatory asset and no deferrals were recorded for 2013 or 2014.
Average rate base		Yr. 1 – $280 million
		Yr. 2 – $296 million
		Yr. 3 – $309 million
Weighted average cost of capital (after-tax)		8.49 percent
Authorized return on common equity		10.4 percent
Earnings sharing		Earnings above an annual earnings threshold of 11.4 percent are to be applied to reduce regulatory assets. In 2012, 2013 and 2014, earnings did not exceed the earnings threshold.
Cost of long-term debt		6.81 percent
Common equity ratio		48 percent
On November 14, 2014, O&R filed a request with the NYSPSC for an increase in the rates it charges for gas service rendered in New York, effective November 1, 2015, of $40.7 million. The filing reflects a return on common equity of 9.75 percent and a common equity ratio of 48 percent. The filing proposes continuation of the current provisions with respect to recovery from customers of the cost of purchased gas, and the reconciliation of actual expenses allocable to the gas business to the amounts for such costs reflected in gas rates for pension and other postretirement benefit costs, environmental remediation and property taxes.
Rockland Electric Company (RECO)
Effective period		May 2010 – July 2014		August 2014 – July 2015
Base rate changes		Yr. 1 – $9.8 million		Yr. 1 – $13.0 million
Amortization to income of net		$(3.9) million over four years and $(4.9) million of deferred storm costs over five years		$0.4 million over three years and $(25.6) million of deferred storm costs over four years
regulatory (assets) and liabilities
Recoverable energy costs		Current rate recovery of purchased power costs.		Continuation of current rate recovery of purchased power costs.
Cost reconciliations		None		None
Average rate base		$148.6 million		$172.2 million
Weighted average cost of capital		8.21 percent		7.83 percent
(after-tax)
Authorized return on common equity		10.3 percent		9.75 percent
Cost of long-term debt		6.16 percent		5.89 percent
Common equity ratio		50 percent		50 percent
Pike County Light & Power Company (Pike) – Electric
Effective period		April 2009 – August 2014		September 2014 – August 2015
Base rate changes(a)		Yr. 1 – $0.9 million		Yr. 1 – $1.25 million
Amortization to income of net regulatory (assets) and liabilities		$0.1 million over 5 years		$(0.7) million of deferred storm costs over five years
Cost reconciliations		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as regulatory liabilities in 2012 and 2013.		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as a regulatory liability in 2014.
(a)	Under the current plan, the earliest that the company can file for a new base rate change is September 1, 2016.
Pike – Gas
Effective period		April 2009 – August 2014		September 2014 – August 2015
Base Rate changes(a)		Yr. 1 – $0.3 million		Yr. 1 – $0.1 million
Amortization to income of net regulatory (assets) and liabilities		None		None
Cost reconciliations		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as regulatory liabilities in 2012 and 2013.		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as a regulatory liability in 2014.
(a)	Under the current plan, the earliest that the company can file for a new base rate change is September 1, 2016.
Other Regulatory Matters
In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures following the arrests of employees for accepting illegal payments from a construction contractor. Subsequently, additional employees were arrested for accepting illegal payments from materials suppliers and an engineering firm. The arrested employees were terminated by the company and have pled guilty or been convicted. Pursuant to NYSPSC orders, a portion of the company’s revenues (currently, $249 million, $32 million and $6 million on an annual basis for electric, gas and steam service, respectively) is being collected subject to potential refund to customers. The amount of electric revenues collected subject to refund, which was established in a different proceeding, and the amount of gas and steam revenues collected subject to refund were not established as indicative of the company’s potential liability in this proceeding. At December 31, 2014, the company had collected an estimated $1,675 million from customers subject to potential refund in connection with this proceeding. In January 2013, a NYSPSC consultant reported its estimate, with which the company does not agree, of $208 million of overcharges with respect to a substantial portion of the company’s construction expenditures from January 2000 to January 2009. The company is disputing the consultant’s estimate, including its determinations as to overcharges regarding specific construction expenditures it selected to review and its methodology of extrapolating such determinations over a substantial portion of the construction expenditures during this period. The NYSPSC’s consultant has not reviewed the company’s other expenditures. The company and NYSPSC staff are exploring a settlement in this proceeding. There is no assurance that there will be a settlement, and any settlement would be subject to NYSPSC approval. At December 31, 2014, the company had a $105 million regulatory liability relating to this matter. The company currently estimates that any additional amount the NYSPSC requires the company to refund to customers in excess of the regulatory liability accrued could range up to an amount based on the NYSPSC consultant’s $208 million estimate of overcharges.
In late October 2012, Superstorm Sandy caused extensive damage to the Utilities’ electric distribution system and interrupted service to approximately 1.4 million customers. Superstorm Sandy also damaged CECONY’s steam system and interrupted service to many of its steam customers. As of December 31, 2014, CECONY and O&R incurred response and restoration costs for Superstorm Sandy of $503 million and $91 million, respectively (including capital expenditures of $148 million and $15 million, respectively). Most of the costs that were not capitalized were deferred for recovery as a regulatory asset under the Utilities’ electric rate plans. See “Regulatory Assets and Liabilities” below. CECONY’s current electric rate plan includes collection from customers of deferred storm costs (including for Superstorm Sandy), subject to refund following NYSPSC review of the costs. In November 2014, O&R requested recovery of deferred storm costs for its New York electric operations, which are subject to NYSPSC review. RECO’s current electric rate plan includes collection from customers of deferred storm costs. See “Rate Plans” above.
In June 2014, the NYSPSC initiated a proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. New York State regulations require gas utilities to qualify and, except in certain circumstances, annually requalify workers that perform fusion to join plastic pipe. The NYSPSC directed the New York gas utilities to provide information in this proceeding about their compliance with the qualification and requalification requirements and related matters; their procedures for compliance with all gas safety regulations; and their annual chief executive officer certifications regarding these and other procedures. CECONY’s qualification and requalification procedures had not included certain required testing to evaluate specimen fuses. In addition, CECONY and O&R had not timely requalified certain workers that had been qualified under their respective procedures to perform fusion to join plastic pipe. CECONY and O&R have requalified their workers who perform plastic pipe fusions. In October 2014, CECONY and O&R submitted for NYSPSC staff review their plans for testing plastic pipe fusions that were performed on their gas delivery systems, additional leakage surveying and reporting.
Regulatory Assets and Liabilities
Regulatory assets and liabilities at December 31, 2014 and 2013 were comprised of the following items:
		Con Edison					CECONY
(Millions of Dollars)		2014			2013		2014		2013
Regulatory assets
Unrecognized pension and other postretirement costs		$	4,846		$	2,730	$	4,609	$	2,610
Future income tax			2,273			2,145		2,166		2,030
Environmental remediation costs			925			938		820		830
Deferred storm costs			319			441		224		334
Revenue taxes			219			207		208		196
Surcharge for New York State assessment			99			78		92		74
Pension and other postretirement benefits deferrals			66			237		42		211
Net electric deferrals			63			83		63		83
Unamortized loss on reacquired debt			57			65		55		62
O&R property tax reconciliation			36			22		-		-
O&R transition bond charges			27			33		-		-
Preferred stock redemption			27			28		27		28
Deferred derivative losses – noncurrent			25			8		23		7
Recoverable energy costs – noncurrent			19			29		17		28
Workers’ compensation			8			12		8		12
Other			147			145		127		134
Regulatory assets – noncurrent			9,156			7,201		8,481		6,639
Deferred derivative losses – current			97			25		92		22
Recoverable energy costs – current			41			4		40		4
Future income tax – current			10			-		-		-
Regulatory assets – current			148			29		132		26
Total Regulatory Assets		$	9,304		$	7,230	$	8,613	$	6,665
Regulatory liabilities
Allowance for cost of removal less salvage		$	598		$	540	$	499	$	453
Property tax reconciliation			295			322		295		322
2014 rate plan rate base revenue deferrals			155			-		155		-
Net unbilled revenue deferrals			138			133		138		133
Prudence proceeding			105			40		105		40
Property tax refunds			87			130		87		130
Long-term interest rate reconciliation			78			105		78		105
New York State income tax rate change			62			-		59		-
Carrying charges on repair allowance and bonus depreciation			58			88		57		87
Pension and other postretirement benefit deferrals			46			50		37		50
World Trade Center settlement proceeds			41			62		41		62
Carrying charges on T&D net plant – electric and steam			21			28		20		20
Electric excess earnings			19			22		18		18
Other			290			208		248		178
Regulatory liabilities – noncurrent			1,993			1,728		1,837		1,598
Refundable energy costs – current			128			100		84		66
Revenue decoupling mechanism			30			34		30		30
Future income tax			24			-		24		-
Deferred derivative gains – current			5			14		4		11
Regulatory liabilities—current			187			148		142		107
Total Regulatory Liabilities		$	2,180		$	1,876	$	1,979	$	1,705
Unrecognized pension and other postretirement costs represents the net regulatory asset associated with the accounting rules for retirement benefits. See Note A.
Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Superstorm Sandy and other major storms that were deferred by the Utilities. See “Other Regulatory Matters,” above.
Net electric deferrals represents the remaining unamortized balance of certain regulatory assets and liabilities of CECONY that were combined effective April 1, 2010 and are being amortized to income over a ten-year period.
Revenue taxes represents the timing difference between taxes collected and paid by the Utilities to fund mass transportation.
Effective March 31, 2009, the NYSPSC authorized CECONY to accrue unbilled electric, gas and steam revenues. CECONY has deferred the net margin on the unbilled revenues for the future benefit of customers by recording a regulatory liability of $138 million and $133 million at December 31, 2014 and 2013, respectively, for the difference between the unbilled revenues and energy cost liabilities.
CECONY [Member]
Regulatory Matters	Note B – 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 O&R’s New Jersey and Pennsylvania regulated utility subsidiaries are approved by utility regulators in those states. 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’ 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. Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases for items such as major storm events 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.
	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.
	Rate base is, in general, the sum of the Utilities’ net plant and working capital less deferred taxes. 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”). The New Jersey Board of Public Utilities (NJBPU) and the Pennsylvania Public Utility Commission (PAPUC) use the rate base balances that would exist at the beginning of the 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 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 is determined by multiplying the Utilities’ rate base by the utility’s 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		April 2010 – December 2013		January 2014 – December 2015
	Base rate changes(a)		Yr. 1 – $420 million		Yr. 1 – $(76.2) million(c)
			Yr. 2 – $420 million		Yr. 2 – $124.0 million(c)
			Yr. 3 – $287 million(b)
	Amortizations to income of net		$(75.3) million over three years		$(37) million over two years, that includes $107 million annually for deferred major storm costs
	regulatory (assets) and liabilities
	Other revenue sources		Retention of $120 million of annual transmission congestion revenues from the sale of transmission rights ($90 million for the period April 1, 2013 to December 31, 2013).		Retention of $90 million of annual transmission congestion revenues.
	Revenue decoupling mechanisms		In 2012 and 2013, the company deferred for customer benefit $59 million and $34 million of revenues, respectively.		In 2014, the company deferred for customer benefit $146 million of revenues.
	Recoverable energy costs		Current rate recovery of purchased power and fuel costs.		Continuation of current rate recovery of purchased power and fuel costs(d).
	Negative revenue adjustments		Potential penalties (up to $350 million annually) if certain performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.		Potential penalties (up to $400 million annually) if certain performance targets are not met. In 2014, the company recorded a $5 million negative revenue adjustment.
	Cost reconciliations(e)		In 2012 and 2013, the company deferred $146 million of net regulatory liabilities and $35 million of net regulatory assets, respectively.		In 2014, the company deferred $57 million of net regulatory liabilities.
	Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
			Transmission and distribution: Yr. 1 –$13,818 million; Yr. 2 – $14,742 million;		Transmission and distribution: Yr. 1 – $16,869 million; Yr. 2 – $17,401 million
			Yr. 3 – $15,414 million		Storm hardening: Yr. 1 – $89 million; Yr. 2 – $177 million
			Enterprise resource project: Yr. 2 – $25 million;		Other: Yr. 1 – $2,034 million; Yr. 2 – $2,102 million
			Yr. 3 -$115 million		The company deferred an immaterial amount as a regulatory liability in 2014.
			Other: Yr. 1 – $1,487 million;
			Yr. 2 – $1,565 million; Yr. 3 – $1,650 million
			The company deferred an immaterial amount and $7 million as a regulatory liability in 2012 and 2013, respectively.
	Average rate base		Yr. 1 – $14,887 million		Yr. 1 – $17,323 million
			Yr. 2 – $15,987 million		Yr. 2 – $18,113 million
			Yr. 3 – $16,826 million
	Weighted average cost of capital (after-tax)		7.76 percent		Yr. 1 – 7.05 percent
					Yr. 2 – 7.08 percent
	Authorized return on common equity		10.15 percent assuming the company achieved austerity measures of $27 million, $20 million and $13 million for Yrs. 1, 2 and 3. Austerity measures were achieved.		9.2 percent
	Earnings sharing		Actual earnings above an annual earnings threshold of 11.15 percent for Yr. 1 and 10.65 percent for Yrs. 2 and 3 were to be applied to reduce regulatory assets for pensions and other postretirement benefits and other costs.		Most earnings above an annual earnings threshold of 9.8 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 $17.5 million above the threshold for the period ended 2013.
	Cost of long-term debt		5.65 percent		Yr. 1 – 5.17 percent
					Yr. 2 – 5.23 percent
	Common equity ratio		48 percent		48 percent
	(a)	$249 million of annual revenues collected from electric customers is subject to potential refund following NYSPSC staff review of costs. See “Other Regulatory Matters” below in this Note B. Revenues for each of 2014 and 2015 include $21 million as funding for major storm reserve.
	(b)	Temporary portion of the increase ($134 million) that was scheduled to go into effect April 1, 2012 was eliminated by the application of available credits.
	(c)	The impact of these base rate changes is being deferred which will result in a $30 million regulatory liability at December 31, 2015.
	(d)	With respect to transmission service provided pursuant to the open access transmission tariff of PJM Interconnection L.L.C. (PJM), the company recovered in 2014 part of charges incurred during 2013 (approximately $20 million) and, commencing in January 2014 and unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. In January 2014, PJM submitted to FERC a request that would substantially increase the charges for the transmission service. CECONY has opposed this increase.
	(e)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.
	In January 2015, CECONY filed a request with the NYSPSC for an electric rate increase of $368 million, effective January 2016. The filing reflects a return on common equity of 10 percent and a common equity ratio of approximately 48 percent.
	The company also is requesting continuation of provisions pursuant to which expenses for pension and other postretirement benefits, variable rate, tax-exempt debt, storms, the impact of new laws and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is requesting reconciliation of property taxes and municipal infrastructure support costs that, unlike the current provisions, would provide for full reconciliation of such costs. The filing also reflects continuation of the revenue decoupling mechanism and provisions for recovery of purchased power and fuel costs from customers.
	CECONY – Gas
	Effective period		October 2010 – December 2013		January 2014 – December 2016
	Base rate changes(a)		Yr. 1 – $47 million		Yr. 1 – $(54.6) million(b)
			Yr. 2 – $48 million		Yr. 2 – $38.6 million(b)
			Yr. 3 – $47 million		Yr. 3 – $56.8 million(b)
	Amortizations to income of net		$(53.1) million over three years		$4 million over three years
	regulatory (assets) and liabilities
	Other revenue sources		Retention of revenues from non-firm customers of up to $58 million and 25 percent of any such revenues above $58 million. The company retained $57 million and $64 million of such revenues in 2012 and 2013, respectively.		Retention of revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. The company retained $70 million of such revenues in 2014.
	Revenue decoupling mechanisms		In 2012 and 2013, the company deferred $22 million and $36 million of regulatory liabilities, respectively.		In 2014, the company deferred $28 million of regulatory liabilities.
	Recoverable energy costs		Current rate recovery of purchased gas costs.		Continuation of current rate recovery of purchased gas costs.
	Negative revenue adjustments		Potential penalties (up to $12.6 million annually)		Potential penalties (up to $33 million in 2014, $44 million in 2015, and $56 million in 2016) if certain gas performance targets are not met. In 2014, the company did not record any negative revenue adjustments.
			if certain gas customer service and system performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.
	Cost reconciliations(c)		In 2012 and 2013, the company deferred $9 million and $26 million of net regulatory assets, respectively.		In 2014, the company deferred $38 million of net regulatory liabilities.
Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
		Gas delivery Yr. 1 – $2,934 million;		Gas delivery Yr. 1 – $3,899 million;
		Yr. 2 – $3,148 million; Yr. 3 – $3,346 million		Yr. 2 – $4,258 million; Yr. 3 – $4,698 million
		For 2012 and 2013, $2.9 million and $9.5 million were deferred as a regulatory liability respectively.		Storm hardening: Yr. 1 – $3 million;
				Yr. 2 – $8 million; Yr. 3 – $30 million
				There were no deferrals recorded in 2014.
Average rate base		Yr. 1 – $3,027 million		Yr. 1 – $3,521 million
		Yr. 2 – $3,245 million		Yr. 2 – $3,863 million
		Yr. 3 – $3,434 million		Yr. 3 – $4,236 million
Weighted average cost of capital		7.46 percent		Yr. 1 – 7.10 percent
(after-tax)				Yr. 2 – 7.13 percent
				Yr. 3 – 7.21 percent
Authorized return on common equity		9.6 percent assuming the company achieved unspecified austerity measures of $4 million and $2 million in 2012 and 2013. Austerity measures were achieved.		9.3 percent
Earnings sharing		Actual earnings did not exceed the thresholds of 10.35 percent in Yr. 1 and 10.15 percent in Yrs. 2 and 3.		Most 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.
Cost of long-term debt		5.57 percent		Yr. 1 – 5.17 percent
				Yr. 2 – 5.23 percent
				Yr. 3 – 5.39 percent
Common equity ratio		48 percent		48 percent
(a)	$32 million of annual revenues collected from gas customers is subject to potential refund. See “Other Regulatory Matters” below.
(b)	The impact of these base rate changes is being deferred which will result in a $32 million regulatory liability at December 31, 2016.
(c)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.
CECONY – Steam
Effective period		October 2010 – December 2013		January 2014 – December 2016
Base rate changes(a)		Yr. 1 – $49.5 million		Yr. 1 – $(22.4) million(b)
		Yr. 2 – $49.5 million		Yr. 2 – $19.8 million(b)
		Yr. 3 – $17.8 million		Yr. 3 – $20.3 million(b)
		Yr. 3 – $31.7 million collected through a surcharge
Amortizations to income of net		$(20.1) million over three years		$37 million over three years
regulatory (assets) and liabilities
Recoverable energy costs		Current rate recovery of purchased power and fuel costs.		Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments		Potential penalties (up to $1 million annually) if certain steam performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.		Potential penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014, the company did not record any negative revenue adjustments.
Cost reconciliations(c)		In 2012 and 2013, the company deferred $12 million and $17 million of net regulatory liabilities, respectively.		In 2014, the company deferred $42 million of net regulatory liabilities.
Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
		Production Yr. 1 – $415 million;		Production Yr. 1 – $1,752 million;
		Yr. 2 – $426 million; Yr. 3 – $433 million		Yr. 2 – $1,732 million; Yr. 3 – $1,720 million
		Distribution: Yr. 1 – $521 million; Yr. 2 – $534 million; Yr. 3 – $543 million		Distribution: Yr. 1 – $6 million; Yr. 2 – $11 million; Yr. 3 – $25 million
		The company reduced its regulatory liability by $0.2 million in 2012 and made no deferral in 2013.		The company reduced its regulatory liability by $1.1 million in 2014.
Average rate base		Yr. 1 – $1,589 million		Yr. 1 – $1,511 million
		Yr. 2 – $1,603 million		Yr. 2 – $1,547 million
		Yr. 3 – $1,613 million		Yr. 3 – $1,604 million
Weighted average cost of		7.46 percent		Yr. 1 – 7.10 percent
capital (after-tax)				Yr. 2 – 7.13 percent
				Yr. 3 – 7.21 percent
Authorized return on common equity		9.6 percent (assuming company achieved unspecified austerity measures of $3 million and $2 million in 2012 and 2013). Austerity measures were achieved.		9.3 percent
Earnings sharing		Weather normalized earnings did not exceed the threshold of 10.35 percent in Yr. 1 and 10.15 percent in Yrs. 2 and 3. In 2013, actual earnings were $0.5 million above the earnings threshold of 10.15 percent.		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.
Cost of long-term debt		5.57 percent		Yr. 1 – 5.17 percent
				Yr. 2 – 5.23 percent
				Yr. 3 – 5.39 percent
Common equity ratio		48 percent		48 percent
(a)	$6 million of annual revenues collected from steam customers is subject to potential refund. See “Other Regulatory Matters” below in this Note B.
(b)	The impact of these base rate changes is being deferred which will result in an $8 million regulatory liability at December 31, 2016.
(c)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.
O&R New York – Electric
Effective period		July 2012 – June 2015
Base rate changes		Yr. 1 – $19.4 million
		Yr. 2 – $8.8 million
		Yr. 3 – $15.2 million
Amortizations to income of net		$(32.2) million over three years
regulatory (assets) and liabilities
Revenue decoupling mechanisms		In 2012, 2013 and 2014, the company deferred for the customer’s benefit $2.6 million, $3.2 million and ($3.4) million.
Recoverable energy costs		Current rate recovery of purchased power and fuel costs.
Negative revenue adjustments		Potential penalties (up to $3 million annually) if certain customer service and system reliability performance targets are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.
Cost reconciliations		In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase to regulatory assets, respectively.
Net utility plant reconciliations		Target levels reflected in rates were:
		Yr. 1 – $678 million; Yr. 2- $704 million; Yr. 3 – $753 million
		The company increased its regulatory liability by $4.2 million in 2012. The company reduced its regulatory, liability by $1.1 million and $2.3 million in 2013 and 2014, respectively.
Average rate base		Yr. 1 – $671 million
		Yr. 2 – $708 million
		Yr. 3 – $759 million
Weighted average cost of capital (after-tax)		Yr. 1 – 7.61 percent
		Yr. 2 – 7.65 percent
		Yr. 3 – 7.48 percent
Authorized return on common equity		Yr. 1 – 9.4 percent
		Yr. 2 – 9.5 percent
		Yr. 3 – 9.6 percent
Earnings sharing		The company recorded a regulatory liability of $1 million for earnings above the sharing threshold under the rate plan as of December 31, 2014.
Cost of long-term debt		Yr. 1 – 6.07 percent
		Yr. 2 – 6.07 percent
		Yr. 3 – 5.64 percent
Common equity ratio		48 percent
On November 14, 2014, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective November 1, 2015, of $33.4 million. The filing reflects a return on common equity of 9.75 percent and a common equity ratio of 48 percent. The filing proposes continuation of the current 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 2009 – December 2014
Base rate changes		Yr. 1 – $9 million
		Yr. 2 – $9 million
		Yr. 3 – $4.6 million
		Yr. 3 – $4.3 million collected through a surcharge
Amortization to income of net regulatory (assets) and liabilities		$(2) million over three years
Revenue decoupling mechanisms		In 2012, 2013 and 2014, the company deferred $4.7 million, $0.7 million and $(0.1) million of regulatory liabilities, respectively.
Recoverable energy costs		Current rate recovery of purchased gas costs.
Negative revenue adjustments		Potential penalties (up to $1.4 million annually) if certain operations and customer service requirements are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.
Cost reconciliations		In 2012, 2013 and 2014, the company deferred $0.7 million, $8.3 million and $8.3 million as net regulatory assets, respectively.
Net utility plant reconciliations		The company deferred $0.7 million in 2012 as a regulatory asset and no deferrals were recorded for 2013 or 2014.
Average rate base		Yr. 1 – $280 million
		Yr. 2 – $296 million
		Yr. 3 – $309 million
Weighted average cost of capital (after-tax)		8.49 percent
Authorized return on common equity		10.4 percent
Earnings sharing		Earnings above an annual earnings threshold of 11.4 percent are to be applied to reduce regulatory assets. In 2012, 2013 and 2014, earnings did not exceed the earnings threshold.
Cost of long-term debt		6.81 percent
Common equity ratio		48 percent
On November 14, 2014, O&R filed a request with the NYSPSC for an increase in the rates it charges for gas service rendered in New York, effective November 1, 2015, of $40.7 million. The filing reflects a return on common equity of 9.75 percent and a common equity ratio of 48 percent. The filing proposes continuation of the current provisions with respect to recovery from customers of the cost of purchased gas, and the reconciliation of actual expenses allocable to the gas business to the amounts for such costs reflected in gas rates for pension and other postretirement benefit costs, environmental remediation and property taxes.
Rockland Electric Company (RECO)
Effective period		May 2010 – July 2014		August 2014 – July 2015
Base rate changes		Yr. 1 – $9.8 million		Yr. 1 – $13.0 million
Amortization to income of net		$(3.9) million over four years and $(4.9) million of deferred storm costs over five years		$0.4 million over three years and $(25.6) million of deferred storm costs over four years
regulatory (assets) and liabilities
Recoverable energy costs		Current rate recovery of purchased power costs.		Continuation of current rate recovery of purchased power costs.
Cost reconciliations		None		None
Average rate base		$148.6 million		$172.2 million
Weighted average cost of capital		8.21 percent		7.83 percent
(after-tax)
Authorized return on common equity		10.3 percent		9.75 percent
Cost of long-term debt		6.16 percent		5.89 percent
Common equity ratio		50 percent		50 percent
Pike County Light & Power Company (Pike) – Electric
Effective period		April 2009 – August 2014		September 2014 – August 2015
Base rate changes(a)		Yr. 1 – $0.9 million		Yr. 1 – $1.25 million
Amortization to income of net regulatory (assets) and liabilities		$0.1 million over 5 years		$(0.7) million of deferred storm costs over five years
Cost reconciliations		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as regulatory liabilities in 2012 and 2013.		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as a regulatory liability in 2014.
(a)	Under the current plan, the earliest that the company can file for a new base rate change is September 1, 2016.
Pike – Gas
Effective period		April 2009 – August 2014		September 2014 – August 2015
Base Rate changes(a)		Yr. 1 – $0.3 million		Yr. 1 – $0.1 million
Amortization to income of net regulatory (assets) and liabilities		None		None
Cost reconciliations		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as regulatory liabilities in 2012 and 2013.		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as a regulatory liability in 2014.
(a)	Under the current plan, the earliest that the company can file for a new base rate change is September 1, 2016.
Other Regulatory Matters
In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures following the arrests of employees for accepting illegal payments from a construction contractor. Subsequently, additional employees were arrested for accepting illegal payments from materials suppliers and an engineering firm. The arrested employees were terminated by the company and have pled guilty or been convicted. Pursuant to NYSPSC orders, a portion of the company’s revenues (currently, $249 million, $32 million and $6 million on an annual basis for electric, gas and steam service, respectively) is being collected subject to potential refund to customers. The amount of electric revenues collected subject to refund, which was established in a different proceeding, and the amount of gas and steam revenues collected subject to refund were not established as indicative of the company’s potential liability in this proceeding. At December 31, 2014, the company had collected an estimated $1,675 million from customers subject to potential refund in connection with this proceeding. In January 2013, a NYSPSC consultant reported its estimate, with which the company does not agree, of $208 million of overcharges with respect to a substantial portion of the company’s construction expenditures from January 2000 to January 2009. The company is disputing the consultant’s estimate, including its determinations as to overcharges regarding specific construction expenditures it selected to review and its methodology of extrapolating such determinations over a substantial portion of the construction expenditures during this period. The NYSPSC’s consultant has not reviewed the company’s other expenditures. The company and NYSPSC staff are exploring a settlement in this proceeding. There is no assurance that there will be a settlement, and any settlement would be subject to NYSPSC approval. At December 31, 2014, the company had a $105 million regulatory liability relating to this matter. The company currently estimates that any additional amount the NYSPSC requires the company to refund to customers in excess of the regulatory liability accrued could range up to an amount based on the NYSPSC consultant’s $208 million estimate of overcharges.
In late October 2012, Superstorm Sandy caused extensive damage to the Utilities’ electric distribution system and interrupted service to approximately 1.4 million customers. Superstorm Sandy also damaged CECONY’s steam system and interrupted service to many of its steam customers. As of December 31, 2014, CECONY and O&R incurred response and restoration costs for Superstorm Sandy of $503 million and $91 million, respectively (including capital expenditures of $148 million and $15 million, respectively). Most of the costs that were not capitalized were deferred for recovery as a regulatory asset under the Utilities’ electric rate plans. See “Regulatory Assets and Liabilities” below. CECONY’s current electric rate plan includes collection from customers of deferred storm costs (including for Superstorm Sandy), subject to refund following NYSPSC review of the costs. In November 2014, O&R requested recovery of deferred storm costs for its New York electric operations, which are subject to NYSPSC review. RECO’s current electric rate plan includes collection from customers of deferred storm costs. See “Rate Plans” above.
In June 2014, the NYSPSC initiated a proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. New York State regulations require gas utilities to qualify and, except in certain circumstances, annually requalify workers that perform fusion to join plastic pipe. The NYSPSC directed the New York gas utilities to provide information in this proceeding about their compliance with the qualification and requalification requirements and related matters; their procedures for compliance with all gas safety regulations; and their annual chief executive officer certifications regarding these and other procedures. CECONY’s qualification and requalification procedures had not included certain required testing to evaluate specimen fuses. In addition, CECONY and O&R had not timely requalified certain workers that had been qualified under their respective procedures to perform fusion to join plastic pipe. CECONY and O&R have requalified their workers who perform plastic pipe fusions. In October 2014, CECONY and O&R submitted for NYSPSC staff review their plans for testing plastic pipe fusions that were performed on their gas delivery systems, additional leakage surveying and reporting.
Regulatory Assets and Liabilities
Regulatory assets and liabilities at December 31, 2014 and 2013 were comprised of the following items:
		Con Edison					CECONY
(Millions of Dollars)		2014			2013		2014		2013
Regulatory assets
Unrecognized pension and other postretirement costs		$	4,846		$	2,730	$	4,609	$	2,610
Future income tax			2,273			2,145		2,166		2,030
Environmental remediation costs			925			938		820		830
Deferred storm costs			319			441		224		334
Revenue taxes			219			207		208		196
Surcharge for New York State assessment			99			78		92		74
Pension and other postretirement benefits deferrals			66			237		42		211
Net electric deferrals			63			83		63		83
Unamortized loss on reacquired debt			57			65		55		62
O&R property tax reconciliation			36			22		-		-
O&R transition bond charges			27			33		-		-
Preferred stock redemption			27			28		27		28
Deferred derivative losses – noncurrent			25			8		23		7
Recoverable energy costs – noncurrent			19			29		17		28
Workers’ compensation			8			12		8		12
Other			147			145		127		134
Regulatory assets – noncurrent			9,156			7,201		8,481		6,639
Deferred derivative losses – current			97			25		92		22
Recoverable energy costs – current			41			4		40		4
Future income tax – current			10			-		-		-
Regulatory assets – current			148			29		132		26
Total Regulatory Assets		$	9,304		$	7,230	$	8,613	$	6,665
Regulatory liabilities
Allowance for cost of removal less salvage		$	598		$	540	$	499	$	453
Property tax reconciliation			295			322		295		322
2014 rate plan rate base revenue deferrals			155			-		155		-
Net unbilled revenue deferrals			138			133		138		133
Prudence proceeding			105			40		105		40
Property tax refunds			87			130		87		130
Long-term interest rate reconciliation			78			105		78		105
New York State income tax rate change			62			-		59		-
Carrying charges on repair allowance and bonus depreciation			58			88		57		87
Pension and other postretirement benefit deferrals			46			50		37		50
World Trade Center settlement proceeds			41			62		41		62
Carrying charges on T&D net plant – electric and steam			21			28		20		20
Electric excess earnings			19			22		18		18
Other			290			208		248		178
Regulatory liabilities – noncurrent			1,993			1,728		1,837		1,598
Refundable energy costs – current			128			100		84		66
Revenue decoupling mechanism			30			34		30		30
Future income tax			24			-		24		-
Deferred derivative gains – current			5			14		4		11
Regulatory liabilities—current			187			148		142		107
Total Regulatory Liabilities		$	2,180		$	1,876	$	1,979	$	1,705
Unrecognized pension and other postretirement costs represents the net regulatory asset associated with the accounting rules for retirement benefits. See Note A.
Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Superstorm Sandy and other major storms that were deferred by the Utilities. See “Other Regulatory Matters,” above.
Net electric deferrals represents the remaining unamortized balance of certain regulatory assets and liabilities of CECONY that were combined effective April 1, 2010 and are being amortized to income over a ten-year period.
Revenue taxes represents the timing difference between taxes collected and paid by the Utilities to fund mass transportation.
Effective March 31, 2009, the NYSPSC authorized CECONY to accrue unbilled electric, gas and steam revenues. CECONY has deferred the net margin on the unbilled revenues for the future benefit of customers by recording a regulatory liability of $138 million and $133 million at December 31, 2014 and 2013, respectively, for the difference between the unbilled revenues and energy cost liabilities.

Capitalization

Capitalization	12 Months Ended
	Dec. 31, 2014
Capitalization	Note C – Capitalization
	Common Stock
	At December 31, 2014 and 2013, Con Edison owned all of the issued and outstanding shares of common stock of the Utilities and the competitive energy businesses. CECONY owns 21,976,200 shares of Con Edison stock, which it purchased prior to 2001 in connection with Con Edison’s stock repurchase plan. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity.
	Capitalization of Con Edison
	The outstanding capitalization for each of the Companies is shown on its Consolidated Statement of Capitalization, and for Con Edison includes the Utilities’ outstanding debt.
	Preferred Stock of CECONY
	In May 2012, CECONY redeemed all of its outstanding shares of $5 Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value).
	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. 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 2015-2019 is as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	560	$	350
	2016		731		650
	2017		6		-
	2018		1,260		1,200
	2019		540		475
	The Utilities have issued $494 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 Utilities.
	The carrying amounts and fair values of long-term debt at December 31, 2014 and 2013 are:
	(Millions of Dollars)	2014				2013
	Long-Term Debt	Carrying		Fair		Carrying		Fair
	(including current	Amount		Value		Amount		Value
	portion)
	Con Edison	$	12,191	$	13,998	$	10,974	$	12,082
	CECONY	$	11,214	$	12,846	$	9,841	$	10,797
	Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $13,362 million and $636 million of the fair value of long-term debt at December 31, 2014 are classified as Level 2 and Level 3, respectively. For CECONY, $12,210 million and $636 million of the fair value of long-term debt at December 31, 2014 are classified as Level 2 and Level 3, respectively (see Note P). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.
	At December 31, 2014 and 2013, long-term debt of Con Edison included $18 million and $22 million, respectively, of Transition Bonds issued in 2004 by O&R’s New Jersey utility subsidiary through a special purpose entity.
	Significant Debt Covenants
	The significant debt covenants under the financing arrangements for the notes of Con Edison and the debentures of CECONY are obligations to pay principal and interest when due, covenants not to consolidate with or merge into any other corporation unless certain conditions are met and, for Con Edison’s notes, covenants that Con Edison shall continue its utility business in New York City and shall not permit Con Edison’s ratio of consolidated debt to consolidated capital to exceed 0.675 to 1. Con Edison’s notes are also subject to cross default provisions with respect to other indebtedness of Con Edison or its material subsidiaries having a then outstanding principal balance in excess of $100 million. CECONY’s debentures have no cross default provisions. The tax-exempt financing arrangements of the Utilities are subject to covenants for the CECONY debentures discussed above and the covenants discussed below. The Companies were in compliance with their significant debt covenants at December 31, 2014.
	The tax-exempt financing arrangements involved the issuance of uncollateralized promissory notes of the Utilities 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 the obligated utility will not at any time exceed 0.65 to 1 and that, subject to certain exceptions, the utility 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 for CECONY, depending on the facility).
CECONY [Member]
Capitalization	Note C – Capitalization
	Common Stock
	At December 31, 2014 and 2013, Con Edison owned all of the issued and outstanding shares of common stock of the Utilities and the competitive energy businesses. CECONY owns 21,976,200 shares of Con Edison stock, which it purchased prior to 2001 in connection with Con Edison’s stock repurchase plan. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity.
	Capitalization of Con Edison
	The outstanding capitalization for each of the Companies is shown on its Consolidated Statement of Capitalization, and for Con Edison includes the Utilities’ outstanding debt.
	Preferred Stock of CECONY
	In May 2012, CECONY redeemed all of its outstanding shares of $5 Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value).
	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. 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 2015-2019 is as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	560	$	350
	2016		731		650
	2017		6		-
	2018		1,260		1,200
	2019		540		475
	The Utilities have issued $494 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 Utilities.
	The carrying amounts and fair values of long-term debt at December 31, 2014 and 2013 are:
	(Millions of Dollars)	2014				2013
	Long-Term Debt	Carrying		Fair		Carrying		Fair
	(including current	Amount		Value		Amount		Value
	portion)
	Con Edison	$	12,191	$	13,998	$	10,974	$	12,082
	CECONY	$	11,214	$	12,846	$	9,841	$	10,797
	Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $13,362 million and $636 million of the fair value of long-term debt at December 31, 2014 are classified as Level 2 and Level 3, respectively. For CECONY, $12,210 million and $636 million of the fair value of long-term debt at December 31, 2014 are classified as Level 2 and Level 3, respectively (see Note P). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.
	At December 31, 2014 and 2013, long-term debt of Con Edison included $18 million and $22 million, respectively, of Transition Bonds issued in 2004 by O&R’s New Jersey utility subsidiary through a special purpose entity.
	Significant Debt Covenants
	The significant debt covenants under the financing arrangements for the notes of Con Edison and the debentures of CECONY are obligations to pay principal and interest when due, covenants not to consolidate with or merge into any other corporation unless certain conditions are met and, for Con Edison’s notes, covenants that Con Edison shall continue its utility business in New York City and shall not permit Con Edison’s ratio of consolidated debt to consolidated capital to exceed 0.675 to 1. Con Edison’s notes are also subject to cross default provisions with respect to other indebtedness of Con Edison or its material subsidiaries having a then outstanding principal balance in excess of $100 million. CECONY’s debentures have no cross default provisions. The tax-exempt financing arrangements of the Utilities are subject to covenants for the CECONY debentures discussed above and the covenants discussed below. The Companies were in compliance with their significant debt covenants at December 31, 2014.
	The tax-exempt financing arrangements involved the issuance of uncollateralized promissory notes of the Utilities 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 the obligated utility will not at any time exceed 0.65 to 1 and that, subject to certain exceptions, the utility 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 for CECONY, depending on the facility).

ShortTerm_Borrowing

Short-Term Borrowing	12 Months Ended
	Dec. 31, 2014
Short-Term Borrowing	Note D – Short-Term Borrowing
	In October 2011, 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 2013, expires in October 2017. There is a maximum of $2.25 billion of credit available through October 2016 and approximately $2.1 billion of credit available from then through October 2017. The full amount is available to CECONY and $1 billion is available to Con Edison, including up to $1.2 billion 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, 2014, Con Edison had $800 million of commercial paper outstanding of which $450 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2014 was 0.4 percent for both Con Edison and CECONY. At December 31, 2013, Con Edison had $1,451 million of commercial paper outstanding of which $1,210 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2013 was 0.2 percent for both Con Edison and CECONY. At December 31, 2014 and 2013, no loans were outstanding under the Credit Agreement and $11 million (including $11 million for CECONY) and $26 million (including $11 million for CECONY) of letters of credit were outstanding under the Credit Agreement.
	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 include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2014 this ratio was 0.51 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. 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, 2014.
	See Note S for information about short-term borrowing between related parties.
CECONY [Member]
Short-Term Borrowing	Note D – Short-Term Borrowing
	In October 2011, 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 2013, expires in October 2017. There is a maximum of $2.25 billion of credit available through October 2016 and approximately $2.1 billion of credit available from then through October 2017. The full amount is available to CECONY and $1 billion is available to Con Edison, including up to $1.2 billion 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, 2014, Con Edison had $800 million of commercial paper outstanding of which $450 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2014 was 0.4 percent for both Con Edison and CECONY. At December 31, 2013, Con Edison had $1,451 million of commercial paper outstanding of which $1,210 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2013 was 0.2 percent for both Con Edison and CECONY. At December 31, 2014 and 2013, no loans were outstanding under the Credit Agreement and $11 million (including $11 million for CECONY) and $26 million (including $11 million for CECONY) of letters of credit were outstanding under the Credit Agreement.
	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 include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2014 this ratio was 0.51 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. 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, 2014.
	See Note S for information about short-term borrowing between related parties.

Pension_Benefits

Pension Benefits	12 Months Ended
	Dec. 31, 2014
Pension Benefits	Note E – Pension Benefits
	Con Edison maintains a tax-qualified, non-contributory pension plan that covers substantially all employees of CECONY and O&R and certain employees of Con Edison’s competitive energy businesses. The plan is designed to comply with the Internal Revenue Code and the Employee Retirement Income Security Act of 1974. In addition, Con Edison maintains additional non-qualified supplemental pension plans.
	Net Periodic Benefit Cost
	The components of the Companies’ total periodic benefit costs for 2014, 2013 and 2012 were as follows:
			Con Edison									CECONY
	(Millions of Dollars)		2014			2013			2012			2014			2013			2012
	Service cost – including administrative expenses		$	227		$	267		$	237		$	211		$	249		$	220
	Interest cost on projected benefit obligation			572			537			547			536			503			513
	Expected return on plan assets			(832	)		(750	)		(705	)		(789	)		(713	)		(670	)
	Recognition of net actuarial loss			618			832			709			586			788			670
	Recognition of prior service costs			4			5			8			2			4			6
	NET PERIODIC BENEFIT COST		$	589		$	891		$	796		$	546		$	831		$	739
	Amortization of regulatory asset*			2			2			2			2			2			2
	TOTAL PERIODIC BENEFIT COST		$	591		$	893		$	798		$	548		$	833		$	741
	Cost capitalized			(225	)		(348	)		(277	)		(212	)		(327	)		(260	)
	Reconciliation to rate level			118			(84	)		(8	)		108			(87	)		(12	)
	Cost charged to operating expenses		$	484		$	461		$	513		$	444		$	419		$	469
	*	Relates to an increase in CECONY’s pension obligation of $45 million from a 1999 special retirement program.
	Funded Status
	The funded status at December 31, 2014, 2013 and 2012 was as follows:
			Con Edison									CECONY
	(Millions of Dollars)		2014			2013			2012			2014			2013			2012
	CHANGE IN PROJECTED BENEFIT OBLIGATION
	Projected benefit obligation at beginning of year		$	12,197		$	13,406		$	11,825		$	11,429		$	12,572		$	11,072
	Service cost – excluding administrative expenses			221			259			224			206			241			209
	Interest cost on projected benefit obligation			572			537			547			536			503			513
	Net actuarial (gain)/loss			2,641			(1,469	)		1,323			2,484			(1,388	)		1,255
	Plan amendments			6			-			-			-			-			-
	Benefits paid			(556	)		(536	)		(513	)		(518	)		(499	)		(477	)
	PROJECTED BENEFIT OBLIGATION AT END OF YEAR		$	15,081		$	12,197		$	13,406		$	14,137		$	11,429		$	12,572
	CHANGE IN PLAN ASSETS
	Fair value of plan assets at beginning of year		$	10,755		$	9,135		$	7,800		$	10,197		$	8,668		$	7,406
	Actual return on plan assets			752			1,310			1,094			715			1,241			1,040
	Employer contributions			578			879			785			535			819			729
	Benefits paid			(556	)		(536	)		(513	)		(518	)		(499	)		(477	)
	Administrative expenses			(34	)		(33	)		(31	)		(32	)		(32	)		(30	)
	FAIR VALUE OF PLAN ASSETS AT END OF YEAR		$	11,495		$	10,755		$	9,135		$	10,897		$	10,197		$	8,668
	FUNDED STATUS		$	(3,586	)	$	(1,442	)	$	(4,271	)	$	(3,240	)	$	(1,232	)	$	(3,904	)
	Unrecognized net loss		$	4,888		$	2,759		$	5,594		$	4,616		$	2,617		$	5,297
	Unrecognized prior service costs			20			17			23			4			6			10
	Accumulated benefit obligation			13,454			11,004			11,911			12,553			10,268			11,116
	The increase in the pension plan’s projected benefit obligation (due primarily to decreased discount rates and, as discussed below, the release of new mortality tables by the Society of Actuaries reflecting longer life expectancies) were the primary causes of the increased pension liability at Con Edison and CECONY of $2,144 million and $2,008 million, respectively, compared with December 31, 2013. For Con Edison, this increase in pension liability resulted in an increase to regulatory assets of $2,101 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, and a charge to OCI of $17 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 the competitive energy businesses and O&R’s New Jersey and Pennsylvania utility subsidiaries.
	For CECONY, the increase in pension liability resulted in an increase to regulatory assets of $1,992 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, a debit to OCI of $3 million (net of taxes) for unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with the competitive energy businesses.
	A portion of the unrecognized net loss and prior service cost for the pension plan, equal to $783 million and $4 million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $740 million and $2 million, respectively, for CECONY.
	At December 31, 2014 and 2013, Con Edison’s investments include $225 million and $201 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $208 million and $183 million, respectively. See Note P. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $289 million and $250 million as of December 31, 2014 and $234 million and $199 million as of December 31, 2013, respectively.
	Assumptions
	The actuarial assumptions were as follows:
			2014			2013			2012
	Weighted-average assumptions used to determine benefit obligations at December 31:
	Discount rate			3.9	%		4.8	%		4.1	%
	Rate of compensation increase
	– CECONY			4.25	%		4.35	%		4.35	%
	– O&R			4	%		4.25	%		4.25	%
	Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
	Discount rate			4.8	%		4.1	%		4.7	%
	Expected return on plan assets			8	%		8	%		8	%
	Rate of compensation increase
	– CECONY			4.35	%		4.35	%		4.35	%
	– O&R			4.25	%		4.25	%		4.25	%
	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 Investors Service (Moody’s) or Standard & Poor’s) 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, they must have a price between 50 percent and 200 percent of the original price, the yield must lie between 1 percent and 20 percent, 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)		2015			2016			2017			2018			2019			2020-2024
Con Edison		$	592		$	615		$	636		$	658		$	678		$	3,642
CECONY			552			574			594			613			632			3,388
Expected Contributions
Based on estimates as of December 31, 2014, the Companies expect to make contributions to the pension plan during 2015 of $756 million (of which $703 million is to be contributed 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 plans.
Plan Assets
The asset allocations for the pension plan at the end of 2014, 2013 and 2012, and the target allocation for 2015 are as follows:
		Target			Plan Assets at December 31,
		Allocation Range
Asset Category		2015			2014			2013			2012
Equity Securities			55% - 65%			58	%		60	%		60	%
Debt Securities			27% - 33%			32	%		30	%		31	%
Real Estate			8% - 12%			10	%		10	%		9	%
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 2015 reflects the results of such a study conducted in 2011.
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 under a three-level hierarchy as defined by the accounting rules for fair value measurements (see Note P).
The fair values of the pension plan assets at December 31, 2014 by asset category are as follows:
(Millions of Dollars)		Level 1			Level 2			Level 3			Total
U.S. Equity(a)		$	3,168		$	-		$	-		$	3,168
International Equity(b)			2,841			361			-			3,202
Private Equity(c)			-			-			114			114
U.S. Government Issued Debt(d)			-			2,113			-			2,113
Corporate Bonds Debt(e)			-			1,351			-			1,351
Structured Assets Debt(f)			-			4			-			4
Other Fixed Income Debt(g)			-			208			-			208
Real Estate(h)			-			-			1,137			1,137
Cash and Cash Equivalents(i)			188			477			-			665
Futures(j)			192			37			-			229
Hedge Funds(k)			-			-			224			224
Total investments		$	6,389		$	4,551		$	1,475		$	12,415
Funds for retiree health benefits(l)			(184	)		(131	)		(43	)		(358	)
Investments (excluding funds for retiree health benefits)		$	6,205		$	4,420		$	1,432		$	12,057
Pending activities(m)												(562	)
Total fair value of plan net assets											$	11,495
(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)	Private Equity consists of global equity funds that are not exchange-traded.
(d)	U.S. Government Issued Debt includes agency and treasury securities.
(e)	Corporate Bonds Debt consists of debt issued by various corporations.
(f)	Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations.
(g)	Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments.
(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.
(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.
(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.
(k)	Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.
(l)	The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F.
(m)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.
The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2014 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)		Beginning			Assets Still Held			Assets Sold			Purchases			Transfer			Ending
		Balance as of			at Reporting Date –			During the			Sales and			In/(Out) of			Balance as of
		January 1, 2014			Unrealized Gains/			Year – Realized			Settlements			Level 3			December 31,
					(Losses)			Gains/(Losses)									2014
Real Estate		$	1,062		$	86		$	20		$	(31	)	$	-		$	1,137
Private Equity			67			12			-			35			-			114
Hedge Funds			206			11			-			7			-			224
Total investments		$	1,335		$	109		$	20		$	11		$	-		$	1,475
Funds for retiree health benefits			(42	)		(1	)		-			-			-			(43	)
Investments (excluding funds for retiree health benefits)		$	1,293		$	108		$	20		$	11		$	-		$	1,432
The fair values of the pension plan assets at December 31, 2013 by asset category are as follows:
(Millions of Dollars)		Level 1			Level 2			Level 3			Total
U.S. Equity(a)		$	3,057		$	-		$	-		$	3,057
International Equity(b)			2,303			871			-			3,174
Private Equity(c)			-			-			67			67
U.S. Government Issued Debt(d)			-			1,855			-			1,855
Corporate Bonds Debt(e)			-			1,151			-			1,151
Structured Assets Debt(f)			-			4			-			4
Other Fixed Income Debt(g)			-			150			-			150
Real Estate(h)			-			-			1,062			1,062
Cash and Cash Equivalents(i)			127			558			-			685
Futures(j)			348			-			-			348
Hedge Funds(k)			-			-			206			206
Total investments		$	5,835		$	4,589		$	1,335		$	11,759
Funds for retiree health benefits(l)			(185	)		(145	)		(42	)		(372	)
Investments(excluding funds for retiree health benefits)		$	5,650		$	4,444		$	1,293		$	11,387
Pending activities(m)												(632	)
Total fair value of plan net assets											$	10,755
(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)	Private Equity consists of global equity funds that are not exchange-traded.
(d)	U.S. Government Issued Debt includes agency and treasury securities.
(e)	Corporate Bonds Debt consists of debt issued by various corporations.
(f)	Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations.
(g)	Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments.
(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.
(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.
(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.
(k)	Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.
(l)	The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F.
(m)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.
The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2013 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)		Beginning			Assets Still Held			Assets Sold			Purchases			Transfer			Ending
		Balance as of			at Reporting Date –			During the			Sales and			In/(Out) of			Balance as of
		January 1, 2013			Unrealized			Year – Realized			Settlements			Level 3			December 31,
					Gains/(Losses)			Gains/(Losses)									2013
Real Estate		$	833		$	114		$	1		$	114		$	-		$	1,062
Private Equity			20			5			-			42			-			67
Hedge Funds			-			6			-			200			-			206
Total investments		$	853		$	125		$	1		$	356		$	-		$	1,335
Funds for retiree health benefits			(31	)		(3	)		-			(8	)		-			(42	)
Investments (excluding funds for retiree health benefits)		$	822		$	122		$	1		$	348		$	-		$	1,293
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)		2014			2013			2012
Con Edison		$	32		$	30		$	23
CECONY			27			26			21
Mortality Table Revision
The Companies adopted revised mortality tables effective December 31, 2014 in the measurement of its pension and other postretirement benefit plan obligations, accounting costs and required contribution amounts. The revised tables reflect the RP-2014 mortality tables published by the Society of Actuaries in October 2014, as adjusted based on the actual experience of the Companies. The new tables incorporate substantial life expectancy improvements relative to the last tables published in 2000 (RP-2000). As a result of the adoption, Con Edison recognized an increase in its pension benefit obligation of approximately $800 million as of December 31, 2014. The Companies, under their current New York rate plans, defer as a regulatory asset or liability, as the case may be, the differences between the actual level of expenses for pension and other postretirement benefits and amounts for those expenses reflected in rates.
CECONY [Member]
Pension Benefits	Note E – Pension Benefits
	Con Edison maintains a tax-qualified, non-contributory pension plan that covers substantially all employees of CECONY and O&R and certain employees of Con Edison’s competitive energy businesses. The plan is designed to comply with the Internal Revenue Code and the Employee Retirement Income Security Act of 1974. In addition, Con Edison maintains additional non-qualified supplemental pension plans.
	Net Periodic Benefit Cost
	The components of the Companies’ total periodic benefit costs for 2014, 2013 and 2012 were as follows:
			Con Edison									CECONY
	(Millions of Dollars)		2014			2013			2012			2014			2013			2012
	Service cost – including administrative expenses		$	227		$	267		$	237		$	211		$	249		$	220
	Interest cost on projected benefit obligation			572			537			547			536			503			513
	Expected return on plan assets			(832	)		(750	)		(705	)		(789	)		(713	)		(670	)
	Recognition of net actuarial loss			618			832			709			586			788			670
	Recognition of prior service costs			4			5			8			2			4			6
	NET PERIODIC BENEFIT COST		$	589		$	891		$	796		$	546		$	831		$	739
	Amortization of regulatory asset*			2			2			2			2			2			2
	TOTAL PERIODIC BENEFIT COST		$	591		$	893		$	798		$	548		$	833		$	741
	Cost capitalized			(225	)		(348	)		(277	)		(212	)		(327	)		(260	)
	Reconciliation to rate level			118			(84	)		(8	)		108			(87	)		(12	)
	Cost charged to operating expenses		$	484		$	461		$	513		$	444		$	419		$	469
	*	Relates to an increase in CECONY’s pension obligation of $45 million from a 1999 special retirement program.
	Funded Status
	The funded status at December 31, 2014, 2013 and 2012 was as follows:
			Con Edison									CECONY
	(Millions of Dollars)		2014			2013			2012			2014			2013			2012
	CHANGE IN PROJECTED BENEFIT OBLIGATION
	Projected benefit obligation at beginning of year		$	12,197		$	13,406		$	11,825		$	11,429		$	12,572		$	11,072
	Service cost – excluding administrative expenses			221			259			224			206			241			209
	Interest cost on projected benefit obligation			572			537			547			536			503			513
	Net actuarial (gain)/loss			2,641			(1,469	)		1,323			2,484			(1,388	)		1,255
	Plan amendments			6			-			-			-			-			-
	Benefits paid			(556	)		(536	)		(513	)		(518	)		(499	)		(477	)
	PROJECTED BENEFIT OBLIGATION AT END OF YEAR		$	15,081		$	12,197		$	13,406		$	14,137		$	11,429		$	12,572
	CHANGE IN PLAN ASSETS
	Fair value of plan assets at beginning of year		$	10,755		$	9,135		$	7,800		$	10,197		$	8,668		$	7,406
	Actual return on plan assets			752			1,310			1,094			715			1,241			1,040
	Employer contributions			578			879			785			535			819			729
	Benefits paid			(556	)		(536	)		(513	)		(518	)		(499	)		(477	)
	Administrative expenses			(34	)		(33	)		(31	)		(32	)		(32	)		(30	)
	FAIR VALUE OF PLAN ASSETS AT END OF YEAR		$	11,495		$	10,755		$	9,135		$	10,897		$	10,197		$	8,668
	FUNDED STATUS		$	(3,586	)	$	(1,442	)	$	(4,271	)	$	(3,240	)	$	(1,232	)	$	(3,904	)
	Unrecognized net loss		$	4,888		$	2,759		$	5,594		$	4,616		$	2,617		$	5,297
	Unrecognized prior service costs			20			17			23			4			6			10
	Accumulated benefit obligation			13,454			11,004			11,911			12,553			10,268			11,116
	The increase in the pension plan’s projected benefit obligation (due primarily to decreased discount rates and, as discussed below, the release of new mortality tables by the Society of Actuaries reflecting longer life expectancies) were the primary causes of the increased pension liability at Con Edison and CECONY of $2,144 million and $2,008 million, respectively, compared with December 31, 2013. For Con Edison, this increase in pension liability resulted in an increase to regulatory assets of $2,101 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, and a charge to OCI of $17 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 the competitive energy businesses and O&R’s New Jersey and Pennsylvania utility subsidiaries.
	For CECONY, the increase in pension liability resulted in an increase to regulatory assets of $1,992 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, a debit to OCI of $3 million (net of taxes) for unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with the competitive energy businesses.
	A portion of the unrecognized net loss and prior service cost for the pension plan, equal to $783 million and $4 million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $740 million and $2 million, respectively, for CECONY.
	At December 31, 2014 and 2013, Con Edison’s investments include $225 million and $201 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $208 million and $183 million, respectively. See Note P. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $289 million and $250 million as of December 31, 2014 and $234 million and $199 million as of December 31, 2013, respectively.
	Assumptions
	The actuarial assumptions were as follows:
			2014			2013			2012
	Weighted-average assumptions used to determine benefit obligations at December 31:
	Discount rate			3.9	%		4.8	%		4.1	%
	Rate of compensation increase
	– CECONY			4.25	%		4.35	%		4.35	%
	– O&R			4	%		4.25	%		4.25	%
	Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
	Discount rate			4.8	%		4.1	%		4.7	%
	Expected return on plan assets			8	%		8	%		8	%
	Rate of compensation increase
	– CECONY			4.35	%		4.35	%		4.35	%
	– O&R			4.25	%		4.25	%		4.25	%
	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 Investors Service (Moody’s) or Standard & Poor’s) 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, they must have a price between 50 percent and 200 percent of the original price, the yield must lie between 1 percent and 20 percent, 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)		2015			2016			2017			2018			2019			2020-2024
Con Edison		$	592		$	615		$	636		$	658		$	678		$	3,642
CECONY			552			574			594			613			632			3,388
Expected Contributions
Based on estimates as of December 31, 2014, the Companies expect to make contributions to the pension plan during 2015 of $756 million (of which $703 million is to be contributed 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 plans.
Plan Assets
The asset allocations for the pension plan at the end of 2014, 2013 and 2012, and the target allocation for 2015 are as follows:
		Target			Plan Assets at December 31,
		Allocation Range
Asset Category		2015			2014			2013			2012
Equity Securities			55% - 65%			58	%		60	%		60	%
Debt Securities			27% - 33%			32	%		30	%		31	%
Real Estate			8% - 12%			10	%		10	%		9	%
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 2015 reflects the results of such a study conducted in 2011.
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 under a three-level hierarchy as defined by the accounting rules for fair value measurements (see Note P).
The fair values of the pension plan assets at December 31, 2014 by asset category are as follows:
(Millions of Dollars)		Level 1			Level 2			Level 3			Total
U.S. Equity(a)		$	3,168		$	-		$	-		$	3,168
International Equity(b)			2,841			361			-			3,202
Private Equity(c)			-			-			114			114
U.S. Government Issued Debt(d)			-			2,113			-			2,113
Corporate Bonds Debt(e)			-			1,351			-			1,351
Structured Assets Debt(f)			-			4			-			4
Other Fixed Income Debt(g)			-			208			-			208
Real Estate(h)			-			-			1,137			1,137
Cash and Cash Equivalents(i)			188			477			-			665
Futures(j)			192			37			-			229
Hedge Funds(k)			-			-			224			224
Total investments		$	6,389		$	4,551		$	1,475		$	12,415
Funds for retiree health benefits(l)			(184	)		(131	)		(43	)		(358	)
Investments (excluding funds for retiree health benefits)		$	6,205		$	4,420		$	1,432		$	12,057
Pending activities(m)												(562	)
Total fair value of plan net assets											$	11,495
(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)	Private Equity consists of global equity funds that are not exchange-traded.
(d)	U.S. Government Issued Debt includes agency and treasury securities.
(e)	Corporate Bonds Debt consists of debt issued by various corporations.
(f)	Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations.
(g)	Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments.
(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.
(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.
(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.
(k)	Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.
(l)	The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F.
(m)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.
The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2014 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)		Beginning			Assets Still Held			Assets Sold			Purchases			Transfer			Ending
		Balance as of			at Reporting Date –			During the			Sales and			In/(Out) of			Balance as of
		January 1, 2014			Unrealized Gains/			Year – Realized			Settlements			Level 3			December 31,
					(Losses)			Gains/(Losses)									2014
Real Estate		$	1,062		$	86		$	20		$	(31	)	$	-		$	1,137
Private Equity			67			12			-			35			-			114
Hedge Funds			206			11			-			7			-			224
Total investments		$	1,335		$	109		$	20		$	11		$	-		$	1,475
Funds for retiree health benefits			(42	)		(1	)		-			-			-			(43	)
Investments (excluding funds for retiree health benefits)		$	1,293		$	108		$	20		$	11		$	-		$	1,432
The fair values of the pension plan assets at December 31, 2013 by asset category are as follows:
(Millions of Dollars)		Level 1			Level 2			Level 3			Total
U.S. Equity(a)		$	3,057		$	-		$	-		$	3,057
International Equity(b)			2,303			871			-			3,174
Private Equity(c)			-			-			67			67
U.S. Government Issued Debt(d)			-			1,855			-			1,855
Corporate Bonds Debt(e)			-			1,151			-			1,151
Structured Assets Debt(f)			-			4			-			4
Other Fixed Income Debt(g)			-			150			-			150
Real Estate(h)			-			-			1,062			1,062
Cash and Cash Equivalents(i)			127			558			-			685
Futures(j)			348			-			-			348
Hedge Funds(k)			-			-			206			206
Total investments		$	5,835		$	4,589		$	1,335		$	11,759
Funds for retiree health benefits(l)			(185	)		(145	)		(42	)		(372	)
Investments(excluding funds for retiree health benefits)		$	5,650		$	4,444		$	1,293		$	11,387
Pending activities(m)												(632	)
Total fair value of plan net assets											$	10,755
(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)	Private Equity consists of global equity funds that are not exchange-traded.
(d)	U.S. Government Issued Debt includes agency and treasury securities.
(e)	Corporate Bonds Debt consists of debt issued by various corporations.
(f)	Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations.
(g)	Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments.
(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.
(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.
(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.
(k)	Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.
(l)	The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F.
(m)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.
The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2013 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)		Beginning			Assets Still Held			Assets Sold			Purchases			Transfer			Ending
		Balance as of			at Reporting Date –			During the			Sales and			In/(Out) of			Balance as of
		January 1, 2013			Unrealized			Year – Realized			Settlements			Level 3			December 31,
					Gains/(Losses)			Gains/(Losses)									2013
Real Estate		$	833		$	114		$	1		$	114		$	-		$	1,062
Private Equity			20			5			-			42			-			67
Hedge Funds			-			6			-			200			-			206
Total investments		$	853		$	125		$	1		$	356		$	-		$	1,335
Funds for retiree health benefits			(31	)		(3	)		-			(8	)		-			(42	)
Investments (excluding funds for retiree health benefits)		$	822		$	122		$	1		$	348		$	-		$	1,293
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)		2014			2013			2012
Con Edison		$	32		$	30		$	23
CECONY			27			26			21
Mortality Table Revision
The Companies adopted revised mortality tables effective December 31, 2014 in the measurement of its pension and other postretirement benefit plan obligations, accounting costs and required contribution amounts. The revised tables reflect the RP-2014 mortality tables published by the Society of Actuaries in October 2014, as adjusted based on the actual experience of the Companies. The new tables incorporate substantial life expectancy improvements relative to the last tables published in 2000 (RP-2000). As a result of the adoption, Con Edison recognized an increase in its pension benefit obligation of approximately $800 million as of December 31, 2014. The Companies, under their current New York rate plans, defer as a regulatory asset or liability, as the case may be, the differences between the actual level of expenses for pension and other postretirement benefits and amounts for those expenses reflected in rates.

Other_Postretirement_Benefits

Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2014
Other Postretirement Benefits	Note F – Other Postretirement Benefits
	The Utilities currently have contributory comprehensive hospital, medical and prescription drug programs for all 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 retired management employees. O&R has a non-contributory life insurance program for retirees. Certain employees of Con Edison’s competitive energy businesses are eligible to receive benefits under these programs.
	Net Periodic Benefit Cost
	The components of the Companies’ net periodic postretirement benefit costs for 2014, 2013 and 2012 were as follows:
			Con Edison												CECONY
	(Millions of Dollars)		2014				2013				2012				2014			2013			2012
	Service cost		$	19			$	23			$	26			$	15		$	18		$	21
	Interest cost on accumulated other postretirement benefit obligation			60				54				73				52			46			63
	Expected return on plan assets			(77	)			(77	)			(85	)			(68	)		(68	)		(75	)
	Recognition of net actuarial loss			57				65				98				51			57			87
	Recognition of prior service cost			(19	)			(27	)			(21	)			(15	)		(23	)		(18	)
	Recognition of transition obligation			-				-				2				-			-			2
	NET PERIODIC POSTRETIREMENT BENEFIT COST		$	40			$	38			$	93			$	35		$	30		$	80
	Cost capitalized			(15	)			(15	)			(32	)			(14	)		(12	)		(28	)
	Reconciliation to rate level			10				58				20				2			50			16
	Cost charged to operating expenses		$	35			$	81			$	81			$	23		$	68		$	68
	Funded Status
	The funded status of the programs at December 31, 2014, 2013 and 2012 were as follows:
			Con Edison												CECONY
	(Millions of Dollars)		2014				2013				2012				2014			2013			2012
	CHANGE IN BENEFIT OBLIGATION
	Benefit obligation at beginning of year		$	1,395			$	1,454			$	1,756			$	1,198		$	1,238		$	1,511
	Service cost			19				23				26				15			18			21
	Interest cost on accumulated postretirement benefit obligation			60				54				73				52			46			63
	Amendments			(12	)			-				(127	)			-			-			(89	)
	Net actuarial loss/(gain)			47				(42	)			(175	)			28			(20	)		(178	)
	Benefits paid and administrative expenses			(134	)			(136	)			(146	)			(125	)		(126	)		(134	)
	Participant contributions			36				38				37				35			38			36
	Medicare prescription subsidy			-				4				10				-			4			8
	BENEFIT OBLIGATION AT END OF YEAR		$	1,411			$	1,395			$	1,454			$	1,203		$	1,198		$	1,238
	CHANGE IN PLAN ASSETS
	Fair value of plan assets at beginning of year		$	1,113			$	1,047			$	947			$	977		$	922		$	840
	Actual return on plan assets			59				153				124				54			134			109
	Employer contributions			7				9				83				7			9			71
	EGWP payments			12				8				-				11			7			-
	Participant contributions			36				38				37				35			38			36
	Benefits paid			(143	)			(142	)			(144	)			(134	)		(133	)		(134	)
	FAIR VALUE OF PLAN ASSETS AT END OF YEAR		$	1,084			$	1,113			$	1,047			$	950		$	977		$	922
	FUNDED STATUS		$	(327	)		$	(282	)		$	(407	)		$	(253	)	$	(221	)	$	(316	)
	Unrecognized net loss		$	78			$	70			$	251			$	45		$	54		$	197
	Unrecognized prior service costs			(71	)			(78	)			(105	)			(46	)		(61	)		(84	)
	In 2012, the Utilities amended their postretirement life and health benefit plans for management employees, resulting in a reduction to the obligation of $102 million. Also in 2012, the Utilities amended the retiree contributions for supplemental postretirement life insurance for CECONY management and weekly retirees, resulting in a reduction to the obligation of $25 million. Also in 2012, the Utilities elected to change the method of receiving the subsidy under Medicare Part D for retiree prescription drug coverage from the Retiree Drug Subsidy to the Employer Group Waiver Plan (EGWP) beginning in January 2013. Participation in the EGWP allows Con Edison to offer substantially the same postretirement benefits to eligible participants while increasing subsidy reimbursements received by the plans from the Federal Government. This change was effective January 2013 and, as a result, the Utilities recognized a reduction to their postretirement health benefit obligation of $306 million as of December 31, 2012, which was recorded as an actuarial gain.
	The increase in the other postretirement benefit plan obligation (due primarily to decreased discount rates) was the primary cause of the increased liability for other postretirement benefits at Con Edison and CECONY of $45 million and $32 million, respectively, compared with December 31, 2013. For Con Edison, this increased liability resulted in an increase to regulatory assets of $14 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, and a charge to OCI of $3 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 the competitive energy businesses and O&R’s New Jersey subsidiary.
	For CECONY, the increase in liability resulted in an increase to regulatory assets of $6 million for unrecognized net losses and unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, a debit to OCI of $2 million (net of taxes) for the unrecognized net losses and an immaterial change to OCI for unrecognized prior service costs associated with the competitive energy businesses.
	A portion of the unrecognized net losses and prior service costs for the other postretirement benefits, equal to $33 million and $(20) million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $29 million and $(14) million, respectively, for CECONY.
	Assumptions
	The actuarial assumptions were as follows:
			2014				2013				2012
	Weighted-average assumptions used to determine benefit obligations at December 31:
	Discount Rate
	CECONY			3.75	%			4.5	%			3.75	%
	O&R			3.85	%			4.75	%			4.05	%
	Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
	Discount Rate
	CECONY			4.5	%			3.75	%			4.55	%
	O&R			4.75	%			4.05	%			4.55	%
	Expected Return on Plan Assets			7.75	%			7.75	%			8.5	%
	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 year ended December 31, 2014 was 5.50 percent, which is assumed to decrease gradually to 4.50 percent by 2018 and remain at that level thereafter. The health care cost trend rate used to determine benefit obligations as of December 31, 2014 was 5.25 percent, which is assumed to decrease gradually to 4.50 percent by 2018 and remain at that level thereafter.
	A one-percentage point change in the assumed health care cost trend rate would have the following effects at December 31, 2015:
			Con Edison								CECONY
			1-Percentage-Point
	(Millions of Dollars)		Increase				Decrease				Increase				Decrease
Effect on accumulated other postretirement benefit obligation		$	(21	)		$	40			$	(43	)		$	57
Effect on service cost and interest cost components for 2014			(2	)			1				(4	)			3
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:
(Millions of Dollars)		2015				2016				2017				2018			2019			2020-2024
BENEFIT PAYMENTS
Con Edison		$	99			$	95			$	94			$	92		$	89		$	419
CECONY			89				85				84				82			79			364
Expected Contributions
Based on estimates as of December 31, 2014, Con Edison expects to make a contribution of $6 million, nearly all of which is for CECONY, to the other postretirement benefit plans in 2015.
Plan Assets
The asset allocations for CECONY’s other postretirement benefit plans at the end of 2014, 2013 and 2012, and the target allocation for 2015 are as follows:
		Target Allocation Range		Plan Assets at
				December 31
Asset Category		2015		2014				2013				2012
Equity Securities		57% - 73%			59	%			61	%			62%
Debt Securities		26% - 44%			41	%			39	%			38%
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 plan assets at December 31, 2014 by asset category as defined by the accounting rules for fair value measurements (see Note P) are as follows:
(Millions of Dollars)		Level 1				Level 2				Level 3				Total
Equity(a)		$	-			$	428			$	-			$	428
Other Fixed Income Debt(b)			-				286				-				286
Cash and Cash Equivalents(c)			-				11				-				11
Total investments		$	-			$	725			$	-			$	725
Funds for retiree health benefits(d)			184				131				43				358
Investments(including funds for retiree health benefits)		$	184			$	856			$	43			$	1,083
Pending activities(e)															1
Total fair value of plan net assets														$	1,084
(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 Barclays Capital Aggregate 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)	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 table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2014 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)		Beginning				Assets Still Held				Assets Sold				Purchases			Transfers			Ending
		Balance as of				at Reporting Date –				During the				Sales and			In/(Out) of			Balance as of
		January 1, 2014				Unrealized				Year – Realized				Settlements			Level 3			December 31,
						Gains/(Losses)				Gains/(Losses)										2014
Total investments		$	-			$	-			$	-			$	-		$	-		$	-
Funds for retiree health benefits			42				1				-				-			-			43
Investments (including funds for retiree health benefits)		$	42			$	1			$	-			$	-		$	-		$	43
The fair values of the plan assets at December 31, 2013 by asset category (see Note P) are as follows:
(Millions of Dollars)		Level 1				Level 2				Level 3				Total
Equity(a)		$	-			$	450			$	-			$	450
Other Fixed Income Debt(b)			-				286				-				286
Cash and Cash Equivalents(c)			-				7				-				7
Total investments		$	-			$	743			$	-			$	743
Funds for retiree health benefits(d)			185				145				42				372
Investments(including funds for retiree health benefits)		$	185			$	888			$	42			$	1,115
Pending activities(e)															(2	)
Total fair value of plan net assets														$	1,113
(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 Barclays Capital Aggregate 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)	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 table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2013 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)		Beginning				Assets Still Held				Assets Sold				Purchases			Transfers			Ending
		Balance as of				at Reporting Date –				During the				Sales and			In/(Out) of			Balance as of
		January 1, 2013				Unrealized				Year – Realized				Settlements			Level 3			December 31,
						Gains/(Losses)				Gains/(Losses)										2013
Total investments		$	-			$	-			$	-			$	-		$	-		$	-
Funds for retiree health benefits			31				3				-				8			-			42
Investments (including funds for retiree health benefits)		$	31			$	3			$	-			$	8		$	-		$	42
Mortality Table Revision
The Companies adopted revised mortality tables effective December 31, 2014 in the measurement of its pension and other postretirement benefit plan obligations, accounting costs, and required contribution amounts as discussed in Note E. As a result of the adoption, Con Edison recognized an increase of less than $10 million in its other postretirement benefits obligation as of December 31, 2014. The Companies, under their current New York rate plans, defer as a regulatory asset or liability, as the case may be, the differences between the actual level of expenses for pension and other postretirement benefits and amounts for those expenses reflected in rates.
CECONY [Member]
Other Postretirement Benefits	Note F – Other Postretirement Benefits
	The Utilities currently have contributory comprehensive hospital, medical and prescription drug programs for all 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 retired management employees. O&R has a non-contributory life insurance program for retirees. Certain employees of Con Edison’s competitive energy businesses are eligible to receive benefits under these programs.
	Net Periodic Benefit Cost
	The components of the Companies’ net periodic postretirement benefit costs for 2014, 2013 and 2012 were as follows:
			Con Edison												CECONY
	(Millions of Dollars)		2014				2013				2012				2014			2013			2012
	Service cost		$	19			$	23			$	26			$	15		$	18		$	21
	Interest cost on accumulated other postretirement benefit obligation			60				54				73				52			46			63
	Expected return on plan assets			(77	)			(77	)			(85	)			(68	)		(68	)		(75	)
	Recognition of net actuarial loss			57				65				98				51			57			87
	Recognition of prior service cost			(19	)			(27	)			(21	)			(15	)		(23	)		(18	)
	Recognition of transition obligation			-				-				2				-			-			2
	NET PERIODIC POSTRETIREMENT BENEFIT COST		$	40			$	38			$	93			$	35		$	30		$	80
	Cost capitalized			(15	)			(15	)			(32	)			(14	)		(12	)		(28	)
	Reconciliation to rate level			10				58				20				2			50			16
	Cost charged to operating expenses		$	35			$	81			$	81			$	23		$	68		$	68
	Funded Status
	The funded status of the programs at December 31, 2014, 2013 and 2012 were as follows:
			Con Edison												CECONY
	(Millions of Dollars)		2014				2013				2012				2014			2013			2012
	CHANGE IN BENEFIT OBLIGATION
	Benefit obligation at beginning of year		$	1,395			$	1,454			$	1,756			$	1,198		$	1,238		$	1,511
	Service cost			19				23				26				15			18			21
	Interest cost on accumulated postretirement benefit obligation			60				54				73				52			46			63
	Amendments			(12	)			-				(127	)			-			-			(89	)
	Net actuarial loss/(gain)			47				(42	)			(175	)			28			(20	)		(178	)
	Benefits paid and administrative expenses			(134	)			(136	)			(146	)			(125	)		(126	)		(134	)
	Participant contributions			36				38				37				35			38			36
	Medicare prescription subsidy			-				4				10				-			4			8
	BENEFIT OBLIGATION AT END OF YEAR		$	1,411			$	1,395			$	1,454			$	1,203		$	1,198		$	1,238
	CHANGE IN PLAN ASSETS
	Fair value of plan assets at beginning of year		$	1,113			$	1,047			$	947			$	977		$	922		$	840
	Actual return on plan assets			59				153				124				54			134			109
	Employer contributions			7				9				83				7			9			71
	EGWP payments			12				8				-				11			7			-
	Participant contributions			36				38				37				35			38			36
	Benefits paid			(143	)			(142	)			(144	)			(134	)		(133	)		(134	)
	FAIR VALUE OF PLAN ASSETS AT END OF YEAR		$	1,084			$	1,113			$	1,047			$	950		$	977		$	922
	FUNDED STATUS		$	(327	)		$	(282	)		$	(407	)		$	(253	)	$	(221	)	$	(316	)
	Unrecognized net loss		$	78			$	70			$	251			$	45		$	54		$	197
	Unrecognized prior service costs			(71	)			(78	)			(105	)			(46	)		(61	)		(84	)
	In 2012, the Utilities amended their postretirement life and health benefit plans for management employees, resulting in a reduction to the obligation of $102 million. Also in 2012, the Utilities amended the retiree contributions for supplemental postretirement life insurance for CECONY management and weekly retirees, resulting in a reduction to the obligation of $25 million. Also in 2012, the Utilities elected to change the method of receiving the subsidy under Medicare Part D for retiree prescription drug coverage from the Retiree Drug Subsidy to the Employer Group Waiver Plan (EGWP) beginning in January 2013. Participation in the EGWP allows Con Edison to offer substantially the same postretirement benefits to eligible participants while increasing subsidy reimbursements received by the plans from the Federal Government. This change was effective January 2013 and, as a result, the Utilities recognized a reduction to their postretirement health benefit obligation of $306 million as of December 31, 2012, which was recorded as an actuarial gain.
	The increase in the other postretirement benefit plan obligation (due primarily to decreased discount rates) was the primary cause of the increased liability for other postretirement benefits at Con Edison and CECONY of $45 million and $32 million, respectively, compared with December 31, 2013. For Con Edison, this increased liability resulted in an increase to regulatory assets of $14 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, and a charge to OCI of $3 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 the competitive energy businesses and O&R’s New Jersey subsidiary.
	For CECONY, the increase in liability resulted in an increase to regulatory assets of $6 million for unrecognized net losses and unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, a debit to OCI of $2 million (net of taxes) for the unrecognized net losses and an immaterial change to OCI for unrecognized prior service costs associated with the competitive energy businesses.
	A portion of the unrecognized net losses and prior service costs for the other postretirement benefits, equal to $33 million and $(20) million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $29 million and $(14) million, respectively, for CECONY.
	Assumptions
	The actuarial assumptions were as follows:
			2014				2013				2012
	Weighted-average assumptions used to determine benefit obligations at December 31:
	Discount Rate
	CECONY			3.75	%			4.5	%			3.75	%
	O&R			3.85	%			4.75	%			4.05	%
	Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
	Discount Rate
	CECONY			4.5	%			3.75	%			4.55	%
	O&R			4.75	%			4.05	%			4.55	%
	Expected Return on Plan Assets			7.75	%			7.75	%			8.5	%
	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 year ended December 31, 2014 was 5.50 percent, which is assumed to decrease gradually to 4.50 percent by 2018 and remain at that level thereafter. The health care cost trend rate used to determine benefit obligations as of December 31, 2014 was 5.25 percent, which is assumed to decrease gradually to 4.50 percent by 2018 and remain at that level thereafter.
	A one-percentage point change in the assumed health care cost trend rate would have the following effects at December 31, 2015:
			Con Edison								CECONY
			1-Percentage-Point
	(Millions of Dollars)		Increase				Decrease				Increase				Decrease
Effect on accumulated other postretirement benefit obligation		$	(21	)		$	40			$	(43	)		$	57
Effect on service cost and interest cost components for 2014			(2	)			1				(4	)			3
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:
(Millions of Dollars)		2015				2016				2017				2018			2019			2020-2024
BENEFIT PAYMENTS
Con Edison		$	99			$	95			$	94			$	92		$	89		$	419
CECONY			89				85				84				82			79			364
Expected Contributions
Based on estimates as of December 31, 2014, Con Edison expects to make a contribution of $6 million, nearly all of which is for CECONY, to the other postretirement benefit plans in 2015.
Plan Assets
The asset allocations for CECONY’s other postretirement benefit plans at the end of 2014, 2013 and 2012, and the target allocation for 2015 are as follows:
		Target Allocation Range		Plan Assets at
				December 31
Asset Category		2015		2014				2013				2012
Equity Securities		57% - 73%			59	%			61	%			62%
Debt Securities		26% - 44%			41	%			39	%			38%
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 plan assets at December 31, 2014 by asset category as defined by the accounting rules for fair value measurements (see Note P) are as follows:
(Millions of Dollars)		Level 1				Level 2				Level 3				Total
Equity(a)		$	-			$	428			$	-			$	428
Other Fixed Income Debt(b)			-				286				-				286
Cash and Cash Equivalents(c)			-				11				-				11
Total investments		$	-			$	725			$	-			$	725
Funds for retiree health benefits(d)			184				131				43				358
Investments(including funds for retiree health benefits)		$	184			$	856			$	43			$	1,083
Pending activities(e)															1
Total fair value of plan net assets														$	1,084
(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 Barclays Capital Aggregate 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)	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 table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2014 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)		Beginning				Assets Still Held				Assets Sold				Purchases			Transfers			Ending
		Balance as of				at Reporting Date –				During the				Sales and			In/(Out) of			Balance as of
		January 1, 2014				Unrealized				Year – Realized				Settlements			Level 3			December 31,
						Gains/(Losses)				Gains/(Losses)										2014
Total investments		$	-			$	-			$	-			$	-		$	-		$	-
Funds for retiree health benefits			42				1				-				-			-			43
Investments (including funds for retiree health benefits)		$	42			$	1			$	-			$	-		$	-		$	43
The fair values of the plan assets at December 31, 2013 by asset category (see Note P) are as follows:
(Millions of Dollars)		Level 1				Level 2				Level 3				Total
Equity(a)		$	-			$	450			$	-			$	450
Other Fixed Income Debt(b)			-				286				-				286
Cash and Cash Equivalents(c)			-				7				-				7
Total investments		$	-			$	743			$	-			$	743
Funds for retiree health benefits(d)			185				145				42				372
Investments(including funds for retiree health benefits)		$	185			$	888			$	42			$	1,115
Pending activities(e)															(2	)
Total fair value of plan net assets														$	1,113
(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 Barclays Capital Aggregate 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)	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 table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2013 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)		Beginning				Assets Still Held				Assets Sold				Purchases			Transfers			Ending
		Balance as of				at Reporting Date –				During the				Sales and			In/(Out) of			Balance as of
		January 1, 2013				Unrealized				Year – Realized				Settlements			Level 3			December 31,
						Gains/(Losses)				Gains/(Losses)										2013
Total investments		$	-			$	-			$	-			$	-		$	-		$	-
Funds for retiree health benefits			31				3				-				8			-			42
Investments (including funds for retiree health benefits)		$	31			$	3			$	-			$	8		$	-		$	42
Mortality Table Revision
The Companies adopted revised mortality tables effective December 31, 2014 in the measurement of its pension and other postretirement benefit plan obligations, accounting costs, and required contribution amounts as discussed in Note E. As a result of the adoption, Con Edison recognized an increase of less than $10 million in its other postretirement benefits obligation as of December 31, 2014. The Companies, under their current New York rate plans, defer as a regulatory asset or liability, as the case may be, the differences between the actual level of expenses for pension and other postretirement benefits and amounts for those expenses reflected in rates.

Environmental_Matters

Environmental Matters	12 Months Ended
	Dec. 31, 2014
Environmental Matters	Note G – 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, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Accrued Liabilities:
	Manufactured gas plant sites		$	684	$	665	$	587	$	562
	Other Superfund Sites			80		84		79		82
	Total		$	764	$	749	$	666	$	644
	Regulatory assets		$	925	$	938	$	820	$	830
	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. Con Edison and CECONY estimate that in 2015 they will incur costs for remediation of approximately $39 million and $35 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. Under their current rate plans, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs.
	Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites at December 31, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Remediation costs incurred		$	29	$	41	$	20	$	35
	Insurance recoveries received*			7		-		7		-
	*	Reduced amount deferred for recovery from customers
	In 2014, 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 $2.7 billion and $2.5 billion, 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, 2014 and 2013, Con Edison and CECONY had accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years of $8 million and $7 million, respectively. The estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Trial courts have begun, and unless otherwise determined by an appellate court may continue, to apply a different standard 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. Under its current rate plans, 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, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Accrued liability – asbestos suits		$	8	$	8	$	7	$	7
	Regulatory assets – asbestos suits		$	8	$	8	$	7	$	7
	Accrued liability – workers’ compensation		$	83	$	87	$	78	$	82
	Regulatory assets – workers’ compensation		$	8	$	12	$	8	$	12
CECONY [Member]
Environmental Matters	Note G – 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, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Accrued Liabilities:
	Manufactured gas plant sites		$	684	$	665	$	587	$	562
	Other Superfund Sites			80		84		79		82
	Total		$	764	$	749	$	666	$	644
	Regulatory assets		$	925	$	938	$	820	$	830
	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. Con Edison and CECONY estimate that in 2015 they will incur costs for remediation of approximately $39 million and $35 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. Under their current rate plans, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs.
	Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites at December 31, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Remediation costs incurred		$	29	$	41	$	20	$	35
	Insurance recoveries received*			7		-		7		-
	*	Reduced amount deferred for recovery from customers
	In 2014, 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 $2.7 billion and $2.5 billion, 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, 2014 and 2013, Con Edison and CECONY had accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years of $8 million and $7 million, respectively. The estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Trial courts have begun, and unless otherwise determined by an appellate court may continue, to apply a different standard 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. Under its current rate plans, 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, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Accrued liability – asbestos suits		$	8	$	8	$	7	$	7
	Regulatory assets – asbestos suits		$	8	$	8	$	7	$	7
	Accrued liability – workers’ compensation		$	83	$	87	$	78	$	82
	Regulatory assets – workers’ compensation		$	8	$	12	$	8	$	12

Other_Material_Contingencies

Other Material Contingencies	12 Months Ended
	Dec. 31, 2014
Other Material Contingencies	Note H – Other Material Contingencies
	Manhattan Steam Main Rupture
	In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately ninety suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for personal injury, property damage and business interruption. The company has 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 to satisfy its liability to others in connection with the suits. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At December 31, 2014, the company has accrued its estimated liability for the suits of $50 million and an insurance receivable in the same amount.
	Manhattan Explosion and Fire
	On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th Street 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 48 people were injured. Additional buildings were also damaged. The National Transportation Safety Board is investigating. The parties to the investigation include the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC (which is also conducting an investigation). Approximately thirty suits are pending against the company seeking generally unspecified damages and, in one case, punitive damages, for personal injury, property damage and business interruption. The company has 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. The company is unable to estimate the amount or range of its possible loss related to the incident. At December 31, 2014, the company had not accrued a liability for the incident.
	Other Contingencies
	See “Other Regulatory Matters” in Note B.
	Guarantees
	Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled $2,547 million and $1,331 million at December 31, 2014 and 2013, respectively.
	A summary, by type and term, of Con Edison’s total guarantees at December 31, 2014 is as follows:
	Guarantee Type	0 – 3		4 – 10		> 10		Total
		years		years		years
		(Millions of Dollars)
	NY Transco	$	1,361	$	-	$	-	$	1,361
	Energy transactions		774		31		96		901
	Renewable electric production projects		248		-		7		255
	Other		30		-		-		30
	Total	$	2,413	$	31	$	103	$	2,547
	NY Transco – Con Edison has guaranteed payment by its subsidiary, Con Edison Transmission, of the contributions it agreed to make in New York Transco LLC (NY Transco). Con Edison Transmission acquired a 46 percent interest in NY Transco when it was formed in 2014. NY Transco’s transmission projects are expected to be developed initially by CECONY and other New York transmission owners and then sold to NY Transco. The development and sale of the projects would be subject to authorizations from the NYSPSC, FERC and other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of Con Edison Transmission’s contributions, which assumed that all the NY Transco projects proposed when NY Transco was formed receive all required regulatory approvals and are completed at 175 percent of their estimated costs and that NY Transco does not use any debt financing for the projects. Guarantee term shown is assumed as the timing of the contributions is not known.
	Energy Transactions – Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in gas, pipeline capacity, transportation, oil, electricity, 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 Con Edison Development guarantee payments associated with the investment in solar and wind energy facilities on behalf of their wholly-owned subsidiaries. In addition, Con Edison Development has entered into two guarantees ($63 million maximum and $31 million maximum, respectively) on behalf of entities (Copper Mountain Solar 2 and Copper Mountain Solar 3, respectively) in which it has a 50 percent interest (see Note Q) in connection with the construction of solar energy facilities. Con Edison Development also provided $3 million in guarantees to Travelers Insurance Company for indemnity agreements for surety bonds in connection with the construction and operation of solar energy facilities performed by its subsidiaries.
	Other – Other guarantees primarily relate to guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects performed by Con Edison Solutions ($25 million). In addition, Con Edison issued a guarantee to the Public Utility Commission of Texas covering obligations of Con Edison Solutions as a retail electric provider. Con Edison’s estimate of the maximum potential obligation for this guarantee is $5 million as of December 31, 2014.
CECONY [Member]
Other Material Contingencies	Note H – Other Material Contingencies
	Manhattan Steam Main Rupture
	In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately ninety suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for personal injury, property damage and business interruption. The company has 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 to satisfy its liability to others in connection with the suits. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At December 31, 2014, the company has accrued its estimated liability for the suits of $50 million and an insurance receivable in the same amount.
	Manhattan Explosion and Fire
	On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th Street 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 48 people were injured. Additional buildings were also damaged. The National Transportation Safety Board is investigating. The parties to the investigation include the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC (which is also conducting an investigation). Approximately thirty suits are pending against the company seeking generally unspecified damages and, in one case, punitive damages, for personal injury, property damage and business interruption. The company has 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. The company is unable to estimate the amount or range of its possible loss related to the incident. At December 31, 2014, the company had not accrued a liability for the incident.
	Other Contingencies
	See “Other Regulatory Matters” in Note B.
	Guarantees
	Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled $2,547 million and $1,331 million at December 31, 2014 and 2013, respectively.
	A summary, by type and term, of Con Edison’s total guarantees at December 31, 2014 is as follows:
	Guarantee Type	0 – 3		4 – 10		> 10		Total
		years		years		years
		(Millions of Dollars)
	NY Transco	$	1,361	$	-	$	-	$	1,361
	Energy transactions		774		31		96		901
	Renewable electric production projects		248		-		7		255
	Other		30		-		-		30
	Total	$	2,413	$	31	$	103	$	2,547
	NY Transco – Con Edison has guaranteed payment by its subsidiary, Con Edison Transmission, of the contributions it agreed to make in New York Transco LLC (NY Transco). Con Edison Transmission acquired a 46 percent interest in NY Transco when it was formed in 2014. NY Transco’s transmission projects are expected to be developed initially by CECONY and other New York transmission owners and then sold to NY Transco. The development and sale of the projects would be subject to authorizations from the NYSPSC, FERC and other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of Con Edison Transmission’s contributions, which assumed that all the NY Transco projects proposed when NY Transco was formed receive all required regulatory approvals and are completed at 175 percent of their estimated costs and that NY Transco does not use any debt financing for the projects. Guarantee term shown is assumed as the timing of the contributions is not known.
	Energy Transactions – Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in gas, pipeline capacity, transportation, oil, electricity, 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 Con Edison Development guarantee payments associated with the investment in solar and wind energy facilities on behalf of their wholly-owned subsidiaries. In addition, Con Edison Development has entered into two guarantees ($63 million maximum and $31 million maximum, respectively) on behalf of entities (Copper Mountain Solar 2 and Copper Mountain Solar 3, respectively) in which it has a 50 percent interest (see Note Q) in connection with the construction of solar energy facilities. Con Edison Development also provided $3 million in guarantees to Travelers Insurance Company for indemnity agreements for surety bonds in connection with the construction and operation of solar energy facilities performed by its subsidiaries.
	Other – Other guarantees primarily relate to guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects performed by Con Edison Solutions ($25 million). In addition, Con Edison issued a guarantee to the Public Utility Commission of Texas covering obligations of Con Edison Solutions as a retail electric provider. Con Edison’s estimate of the maximum potential obligation for this guarantee is $5 million as of December 31, 2014.

Electricity_Purchase_Agreement

Electricity Purchase Agreements	12 Months Ended
	Dec. 31, 2014
Electricity Purchase Agreements	Note I – Electricity Purchase Agreements
	CECONY has long-term electricity purchase agreements with non-utility generators and others for generating capacity. The company recovers its purchased power costs in accordance with provisions approved by the NYSPSC. See “Recoverable Energy Costs” in Note A.
	At December 31, 2014, the significant terms of the electricity purchase agreements were as follows:
	Facility		Equity Owner		Plant				Contracted				Contract				Contract
					Output				Output				Start				Term
					(MW)				(MW)				Date				(Years)
	Brooklyn Navy Yard		Brooklyn Navy Yard Cogeneration Partners, LP			322				291				November 1996				40
	Linden Cogeneration		Cogen Technologies Linden Venture, LP			1,035				607				May-92				25
	Indeck Corinth		Indeck Energy Services of Corinth, Inc.			147				131				Jul-95				20
	Indian Point		Entergy Nuclear Power Marketing, LLC			2,311				500				August 2001				16
	Astoria Energy		Astoria Energy, LLC			640				500				May-06				10
	Assuming performance by the parties to the electricity purchase agreements, CECONY is obligated over the terms of the agreements to make capacity and other fixed payments.
	The future capacity and other fixed payments under the contracts are estimated to be as follows:
	(Millions of		2015				2016				2017				2018				2019		All Years
	Dollars)																				Thereafter
	CECONY		$	252			$	186			$	135			$	62			$	53	$	820
	For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the agreements for capacity, energy and other fixed payments in 2014, 2013 and 2012 were as follows:
			For the Years Ended
			December 31,
	(Millions of Dollars)		2014				2013				2012
	Brooklyn Navy Yard		$	133			$	118			$	93
	Linden Cogeneration			381				346				297
	Indeck Corinth			80				79				66
	Indian Point			247				220				204
	Astoria Energy			230				183				181
	Selkirk*			144				215				196
	Independence*			97				121				127
	Total		$	1,312			$	1,282			$	1,164
	*	Contract term ended in 2014
CECONY [Member]
Electricity Purchase Agreements	Note I – Electricity Purchase Agreements
	CECONY has long-term electricity purchase agreements with non-utility generators and others for generating capacity. The company recovers its purchased power costs in accordance with provisions approved by the NYSPSC. See “Recoverable Energy Costs” in Note A.
	At December 31, 2014, the significant terms of the electricity purchase agreements were as follows:
	Facility		Equity Owner		Plant				Contracted				Contract				Contract
					Output				Output				Start				Term
					(MW)				(MW)				Date				(Years)
	Brooklyn Navy Yard		Brooklyn Navy Yard Cogeneration Partners, LP			322				291				November 1996				40
	Linden Cogeneration		Cogen Technologies Linden Venture, LP			1,035				607				May-92				25
	Indeck Corinth		Indeck Energy Services of Corinth, Inc.			147				131				Jul-95				20
	Indian Point		Entergy Nuclear Power Marketing, LLC			2,311				500				August 2001				16
	Astoria Energy		Astoria Energy, LLC			640				500				May-06				10
	Assuming performance by the parties to the electricity purchase agreements, CECONY is obligated over the terms of the agreements to make capacity and other fixed payments.
	The future capacity and other fixed payments under the contracts are estimated to be as follows:
	(Millions of		2015				2016				2017				2018				2019		All Years
	Dollars)																				Thereafter
	CECONY		$	252			$	186			$	135			$	62			$	53	$	820
	For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the agreements for capacity, energy and other fixed payments in 2014, 2013 and 2012 were as follows:
			For the Years Ended
			December 31,
	(Millions of Dollars)		2014				2013				2012
	Brooklyn Navy Yard		$	133			$	118			$	93
	Linden Cogeneration			381				346				297
	Indeck Corinth			80				79				66
	Indian Point			247				220				204
	Astoria Energy			230				183				181
	Selkirk*			144				215				196
	Independence*			97				121				127
	Total		$	1,312			$	1,282			$	1,164
	*	Contract term ended in 2014

Leases

Leases	12 Months Ended
	Dec. 31, 2014
Leases	Note J – Leases
	Con Edison’s subsidiaries lease electric transmission facilities, gas distribution facilities, land, office buildings and equipment. In accordance with the accounting rules for leases, these leases are classified as either capital leases or operating leases. Most of the operating leases provide the option to renew at the fair rental value for future periods. Generally, it is expected that leases will be renewed or replaced in the normal course of business.
	Capital leases: For ratemaking purposes capital leases are treated as operating leases; therefore, in accordance with the accounting rules for regulated operations, the amortization of the leased asset is based on the rental payments recovered from customers. The following assets under capital leases are included in the Companies’ consolidated balance sheets at December 31, 2014 and 2013:
		Con Edison					CECONY
	(Millions of Dollars)	2014		2013			2014		2013
	UTILITY PLANT
	Common	$	3	$	3		$	1	$	2
	The accumulated amortization of the capital leases for Con Edison and CECONY was $1.8 million and $0.8 million, respectively at December 31, 2014, and $1.0 million and $0.6 million, respectively at December 31, 2013.
	The future minimum lease commitments for the above assets are as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	1	$	1
	2016		1		1
	2017		-		-
	2018		-		-
	2019		-		-
	All years thereafter		-		-
	Total		2		2
	Less: amount representing interest		1		1
	Present value of net minimum lease payment	$	1	$	1
	Operating leases: The future minimum lease commitments under the Companies’ non-cancelable operating lease agreements are as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	18	$	14
	2016		17		13
	2017		16		12
	2018		16		12
	2019		14		10
	All years thereafter		72		51
	Total	$	153	$	112
	Lease In/Lease Out Transactions
	In each of 1997 and 1999, Con Edison Development entered into transactions in which it leased property and then immediately subleased the properties back to the lessor (termed “Lease In/Lease Out,” or LILO transactions). The transactions respectively involved electric generating and gas distribution facilities in the Netherlands, with a total investment of $259 million. The transactions were financed with $93 million of equity and $166 million of non-recourse, long-term debt secured by the underlying assets. In accordance with the accounting rules for leases, Con Edison accounted for the two LILO transactions as leveraged leases. Accordingly, the company’s investment in these leases, net of non-recourse debt, was carried as a single amount in Con Edison’s consolidated balance sheet and income was recognized pursuant to a method that incorporated a level rate of return for those years when net investment in the lease was positive. At December 31, 2012, the company’s net investment in the LILO transactions was $(76) million, comprised of a $228 million gross investment less $304 million of deferred tax liabilities. During 2013, as discussed below, the company terminated its LILO transactions and at December 31, 2013 no longer had an investment recorded for these leases in its consolidated balance sheet.
	On audit of Con Edison’s tax returns, the Internal Revenue Service (IRS) disallowed tax losses in connection with the 1997 LILO transactions. In October 2009, the United States Court of Federal Claims issued a decision in favor of the company which, among other things, concluded that the tax losses claimed by the company were allowable. In January 2013, the United States Court of Appeals for the Federal Circuit reversed the October 2009 trial court decision. In June 2013, Con Edison entered into a closing agreement with the IRS regarding the 1997 and 1999 LILO transactions.
	As a result of the January 2013 Court of Appeals decision, in 2013, Con Edison recorded an after-tax charge of $150 million to reflect, as required by the accounting rules for leveraged lease transactions, the recalculation of the accounting effect of the LILO transactions based on the revised after-tax cash flows projected from the inception of the leveraged leases as well as the interest on the potential tax liability resulting from the disallowance of federal and state income tax losses for the LILO transactions. Also, in 2013, the LILO transactions were terminated, as a result of which the company realized a $55 million gain (after-tax). In 2014, adjustments were made to the interest accrued on the liability and the related taxes resulting in a decrease to net income of $1 million.
	The effect on Con Edison’s consolidated income statement for the twelve months ended as of December 31, 2014 and 2013 was as follows:
		For the Years Ended
		December 31,
	(Millions of Dollars)	2014		2013
	Increase/(decrease) to non-utility operating revenues	$	-	$	(27	)
	(Increase)/decrease to other interest expense		13		(131	)
	Income tax benefit/(expense)		-14		63
	Total increase/(decrease) in net income		($1)		($95)
	The transactions did not impact earnings in 2012.
	In January 2013, to defray interest charges, the company deposited $447 million with federal and state tax agencies relating primarily to the potential tax liability from the LILO transactions in past tax years and interest thereon. During 2013, $125 million of the deposit was returned from the IRS at the company’s request. Also in 2013, the deposit balance was reduced by an additional $48 million, due to a $10 million refund from the IRS and the application of $38 million toward the settlement of tax and interest for prior tax years, primarily relating to tax liability from the LILO transactions. In the first quarter of 2014, Con Edison applied the remainder of the deposit against its federal and state tax liabilities, including interest, for other tax years.
CECONY [Member]
Leases	Note J – Leases
	Con Edison’s subsidiaries lease electric transmission facilities, gas distribution facilities, land, office buildings and equipment. In accordance with the accounting rules for leases, these leases are classified as either capital leases or operating leases. Most of the operating leases provide the option to renew at the fair rental value for future periods. Generally, it is expected that leases will be renewed or replaced in the normal course of business.
	Capital leases: For ratemaking purposes capital leases are treated as operating leases; therefore, in accordance with the accounting rules for regulated operations, the amortization of the leased asset is based on the rental payments recovered from customers. The following assets under capital leases are included in the Companies’ consolidated balance sheets at December 31, 2014 and 2013:
		Con Edison					CECONY
	(Millions of Dollars)	2014		2013			2014		2013
	UTILITY PLANT
	Common	$	3	$	3		$	1	$	2
	The accumulated amortization of the capital leases for Con Edison and CECONY was $1.8 million and $0.8 million, respectively at December 31, 2014, and $1.0 million and $0.6 million, respectively at December 31, 2013.
	The future minimum lease commitments for the above assets are as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	1	$	1
	2016		1		1
	2017		-		-
	2018		-		-
	2019		-		-
	All years thereafter		-		-
	Total		2		2
	Less: amount representing interest		1		1
	Present value of net minimum lease payment	$	1	$	1
	Operating leases: The future minimum lease commitments under the Companies’ non-cancelable operating lease agreements are as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	18	$	14
	2016		17		13
	2017		16		12
	2018		16		12
	2019		14		10
	All years thereafter		72		51
	Total	$	153	$	112
	Lease In/Lease Out Transactions
	In each of 1997 and 1999, Con Edison Development entered into transactions in which it leased property and then immediately subleased the properties back to the lessor (termed “Lease In/Lease Out,” or LILO transactions). The transactions respectively involved electric generating and gas distribution facilities in the Netherlands, with a total investment of $259 million. The transactions were financed with $93 million of equity and $166 million of non-recourse, long-term debt secured by the underlying assets. In accordance with the accounting rules for leases, Con Edison accounted for the two LILO transactions as leveraged leases. Accordingly, the company’s investment in these leases, net of non-recourse debt, was carried as a single amount in Con Edison’s consolidated balance sheet and income was recognized pursuant to a method that incorporated a level rate of return for those years when net investment in the lease was positive. At December 31, 2012, the company’s net investment in the LILO transactions was $(76) million, comprised of a $228 million gross investment less $304 million of deferred tax liabilities. During 2013, as discussed below, the company terminated its LILO transactions and at December 31, 2013 no longer had an investment recorded for these leases in its consolidated balance sheet.
	On audit of Con Edison’s tax returns, the Internal Revenue Service (IRS) disallowed tax losses in connection with the 1997 LILO transactions. In October 2009, the United States Court of Federal Claims issued a decision in favor of the company which, among other things, concluded that the tax losses claimed by the company were allowable. In January 2013, the United States Court of Appeals for the Federal Circuit reversed the October 2009 trial court decision. In June 2013, Con Edison entered into a closing agreement with the IRS regarding the 1997 and 1999 LILO transactions.
	As a result of the January 2013 Court of Appeals decision, in 2013, Con Edison recorded an after-tax charge of $150 million to reflect, as required by the accounting rules for leveraged lease transactions, the recalculation of the accounting effect of the LILO transactions based on the revised after-tax cash flows projected from the inception of the leveraged leases as well as the interest on the potential tax liability resulting from the disallowance of federal and state income tax losses for the LILO transactions. Also, in 2013, the LILO transactions were terminated, as a result of which the company realized a $55 million gain (after-tax). In 2014, adjustments were made to the interest accrued on the liability and the related taxes resulting in a decrease to net income of $1 million.
	The effect on Con Edison’s consolidated income statement for the twelve months ended as of December 31, 2014 and 2013 was as follows:
		For the Years Ended
		December 31,
	(Millions of Dollars)	2014		2013
	Increase/(decrease) to non-utility operating revenues	$	-	$	(27	)
	(Increase)/decrease to other interest expense		13		(131	)
	Income tax benefit/(expense)		-14		63
	Total increase/(decrease) in net income		($1)		($95)
	The transactions did not impact earnings in 2012.
	In January 2013, to defray interest charges, the company deposited $447 million with federal and state tax agencies relating primarily to the potential tax liability from the LILO transactions in past tax years and interest thereon. During 2013, $125 million of the deposit was returned from the IRS at the company’s request. Also in 2013, the deposit balance was reduced by an additional $48 million, due to a $10 million refund from the IRS and the application of $38 million toward the settlement of tax and interest for prior tax years, primarily relating to tax liability from the LILO transactions. In the first quarter of 2014, Con Edison applied the remainder of the deposit against its federal and state tax liabilities, including interest, for other tax years.

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2014
Goodwill	Note K – Goodwill
	In 2014 and 2013, Con Edison completed impairment tests for its goodwill of $406 million related to the O&R merger, and determined that it was not impaired. For the impairment test, $245 million and $161 million of the goodwill were allocated to CECONY and O&R, respectively. In 2014 and 2013, Con Edison also completed impairment tests for the goodwill of $23 million related to two energy services companies acquired by Con Edison Solutions and a gas storage company acquired by Con Edison Development, and determined that the goodwill was not impaired. Estimates of future cash flows, projected growth rates, and discount rates inherent in the cash flow estimates for the energy services companies and gas storage company may vary significantly from actual results, which could result in a future impairment of goodwill.
	Prior to 2014, Con Edison performed its annual goodwill impairment test on either January 1 or December 31. During the fourth quarter of 2014, Con Edison changed its annual goodwill impairment testing date from January 1 and December 31 to October 1. This change is preferable under the circumstances as it aligns the timing of the annual goodwill impairment test with the strategic planning and budgeting process, which will allow Con Edison to utilize the updated strategic business plans that result from the budget process in the discounted cash flow analyses that it uses to estimate the fair value of its reporting units. This change does not accelerate, delay, avoid or cause an impairment charge, nor does this change result in adjustments to previously issued financial statements. The annual goodwill impairment testing was performed as of October 1, 2014. Consideration was also given to the period between the testing date and December 31, 2014, in order to conclude that no facts or circumstances have arisen that would lead to a different conclusion as of December 31, 2014.
CECONY [Member]
Goodwill	Note K – Goodwill
	In 2014 and 2013, Con Edison completed impairment tests for its goodwill of $406 million related to the O&R merger, and determined that it was not impaired. For the impairment test, $245 million and $161 million of the goodwill were allocated to CECONY and O&R, respectively. In 2014 and 2013, Con Edison also completed impairment tests for the goodwill of $23 million related to two energy services companies acquired by Con Edison Solutions and a gas storage company acquired by Con Edison Development, and determined that the goodwill was not impaired. Estimates of future cash flows, projected growth rates, and discount rates inherent in the cash flow estimates for the energy services companies and gas storage company may vary significantly from actual results, which could result in a future impairment of goodwill.
	Prior to 2014, Con Edison performed its annual goodwill impairment test on either January 1 or December 31. During the fourth quarter of 2014, Con Edison changed its annual goodwill impairment testing date from January 1 and December 31 to October 1. This change is preferable under the circumstances as it aligns the timing of the annual goodwill impairment test with the strategic planning and budgeting process, which will allow Con Edison to utilize the updated strategic business plans that result from the budget process in the discounted cash flow analyses that it uses to estimate the fair value of its reporting units. This change does not accelerate, delay, avoid or cause an impairment charge, nor does this change result in adjustments to previously issued financial statements. The annual goodwill impairment testing was performed as of October 1, 2014. Consideration was also given to the period between the testing date and December 31, 2014, in order to conclude that no facts or circumstances have arisen that would lead to a different conclusion as of December 31, 2014.

Income_Tax

Income Tax	12 Months Ended
	Dec. 31, 2014
Income Tax	Note L – Income Tax
	The components of income tax are as follows:
		Con Edison									CECONY
	(Millions of Dollars)	2014			2013			2012			2014			2013			2012
	State
	Current	$	59		$	151		$	29		$	66		$	111		$	53
	Deferred		61			(70	)		97			65			(14	)		53
	Federal
	Current		(9	)		285			(13	)		158			187			110
	Deferred		463			115			493			271			241			318
	Amortization of investment tax credits		(6	)		(5	)		(6	)		(5	)		(5	)		(5	)
	Total income tax expense	$	568		$	476		$	600		$	555		$	520		$	529
	The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows:
		Con Edison						CECONY
	(Millions of Dollars)	2014			2013			2014			2013
	Deferred tax liabilities:
	Property basis differences	$	7,510		$	7,012		$	6,938		$	6,424
	Unrecognized pension and other postretirement costs		1,968			1,109			1,872			1,060
	Regulatory asset – future income tax		910			871			863			825
	Environmental remediation costs		376			381			333			337
	Deferred storm costs		129			179			91			136
	Equity investments		168			21			-			-
	Other regulatory assets		347			402			300			364
	Unamortized investment tax credits		126			43			37			42
	Total deferred tax liabilities and investment tax credits		11,534			10,018			10,434			9,188
	Deferred tax assets:
	Accrued pension and other postretirement costs		1,306			458			1,155			364
	Regulatory liabilities		615			604			574			569
	Superfund and other environmental costs		306			301			264			256
	Asset retirement obligations		77			58			75			58
	Loss carryforwards		21			12			-			-
	Loss carryforwards, valuation reserve		(11	)		(12	)		-			-
	Other		272			253			203			209
	Total deferred tax assets		2,586			1,674			2,271			1,456
	Net deferred tax liabilities and investment tax credits	$	8,948		$	8,344		$	8,163		$	7,732
	Deferred income taxes and investment tax credits – noncurrent	$	9,076		$	8,466		$	8,257		$	7,832
	Deferred tax assets – current		(128	)		(122	)		(94	)		(100	)
	Net deferred tax liabilities and investment tax credits	$	8,948		$	8,344		$	8,163		$	7,732
	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)	2014			2013			2012			2014			2013			2012
	STATUTORY TAX RATE
	Federal		35	%		35	%		35	%		35	%		35	%		35	%
	Changes in computed taxes resulting from:
	State income tax		5			4			4			5			5			4
	Cost of removal		(5	)		(5	)		(4	)		(5	)		(5	)		(4	)
	Manufacturing deduction		-			(1	)		-			-			-			-
	Other		(1	)		(2	)		(1	)		(1	)		(1	)		(1	)
	Effective tax rate		34	%		31	%		34	%		34	%		34	%		34	%
	Con Edison has a net operating loss carryforward available from the years 1999 through 2014 for which a deferred tax asset of $21 million has been recognized and will not expire until the years 2019 through 2034. An $11 million valuation allowance for New York City income tax purpose has been provided; as it is not more likely than not that the deferred tax asset will be realized.
	In September 2013, the IRS issued final regulations, effective in 2014, that provide guidance on the appropriate tax treatment of costs incurred to acquire, produce or improve tangible property, as well as routine maintenance and repair costs. Proposed regulations were issued addressing the tax treatment of asset dispositions. The application of these regulations did not have a material impact on the Companies’ financial position, results of operations or liquidity.
	In March 2014, tax legislation was enacted in the State of New York that reduced the corporate franchise tax rate from 7.1 percent to 6.5 percent, beginning January 1, 2016. The application of this legislation decreased Con Edison’s accumulated deferred tax liabilities by $74 million ($69 million for CECONY), decreased Con Edison’s regulatory asset for future income tax by $11 million ($10 million for CECONY) and increased Con Edison’s regulatory liability by $62 million ($59 million for CECONY). The impact of this tax legislation on Con Edison’s effective tax rate was not material, and there was no impact on CECONY’s effective tax rate for the year ended December 31, 2014.
	Under the Taxpayer Relief Act of 2012, 50 percent bonus depreciation expired on December 31, 2013. On December 19, 2014, President Obama signed into law the Tax Increase Prevention Act of 2014, which extended bonus depreciation for another year through December 31, 2014. As a result of the extension of bonus depreciation to 2014, Con Edison filed a refund request with the IRS in January 2015 to recover $224 million ($128 million attributable to CECONY) in estimated federal tax payments.
	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.
	In 2014 following the conclusion of its IRS audit, Con Edison filed amended state tax returns (primarily New York) for tax years 1998 through 2011. As a result of positions taken on the amended state tax returns, Con Edison increased its estimated liabilities for uncertain tax positions by $27 million ($2 million attributable to CECONY). The amended returns contain uncertain tax positions unique to the states, and the returns remain open for examination. The federal tax returns for 2011 through 2013 remain open for examination. These changes to the Companies’ estimated liabilities for uncertain tax positions had an immaterial impact on income tax expense for the year ended December 31, 2014.
	A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows:
		Con Edison									CECONY
	(Millions of Dollars)	2014			2013			2012			2014			2013			2012
	Balance at January 1,	$	9		$	86		$	130		$	-		$	74		$	114
	Additions based on tax positions related to the current year		-			5			12			-			-			11
	Additions based on tax positions of prior years		27			253			-			2			-			-
	Reductions for tax positions of prior years		(2	)		(86	)		(57	)		-			(74	)		(52	)
	Settlements		-			(249	)		1			-			-			1
Balance at December 31,	$	34		$	9		$	86		$	2		$	-		$	74
As of December 31, 2014, Con Edison reasonably expects to resolve approximately $26 million ($17 million, net of federal taxes) of its uncertainties related to certain tax matters within the next twelve months. Favorable resolution would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $2 million ($1 million, net of federal taxes), of which the entire amount, if recognized, would reduce CECONY’s effective tax rate.
The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In 2014 and 2012, the Companies recognized an immaterial amount of interest and no penalties for uncertain tax positions in their consolidated income statements. In 2013, Con Edison recognized $121 million of interest expense ($131 million related to the LILO transactions (see “Lease In/Lease Out Transactions” in Note J), less a reduction of $10 million in accrued interest expense primarily associated with repair allowance deductions and reversing other uncertain tax positions in 2013). At December 31, 2014 and 2013, the Companies recognized an immaterial amount of interest and no penalties in their consolidated balance sheets.
At December 31, 2014, the total amount of unrecognized tax benefits that, if recognized, would reduce the Companies’ effective tax rate is $34 million ($22 million, net of federal taxes) with $2 million ($1 million, net of federal taxes) attributable to CECONY.
CECONY [Member]
Income Tax	Note L – Income Tax
	The components of income tax are as follows:
		Con Edison									CECONY
	(Millions of Dollars)	2014			2013			2012			2014			2013			2012
	State
	Current	$	59		$	151		$	29		$	66		$	111		$	53
	Deferred		61			(70	)		97			65			(14	)		53
	Federal
	Current		(9	)		285			(13	)		158			187			110
	Deferred		463			115			493			271			241			318
	Amortization of investment tax credits		(6	)		(5	)		(6	)		(5	)		(5	)		(5	)
	Total income tax expense	$	568		$	476		$	600		$	555		$	520		$	529
	The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows:
		Con Edison						CECONY
	(Millions of Dollars)	2014			2013			2014			2013
	Deferred tax liabilities:
	Property basis differences	$	7,510		$	7,012		$	6,938		$	6,424
	Unrecognized pension and other postretirement costs		1,968			1,109			1,872			1,060
	Regulatory asset – future income tax		910			871			863			825
	Environmental remediation costs		376			381			333			337
	Deferred storm costs		129			179			91			136
	Equity investments		168			21			-			-
	Other regulatory assets		347			402			300			364
	Unamortized investment tax credits		126			43			37			42
	Total deferred tax liabilities and investment tax credits		11,534			10,018			10,434			9,188
	Deferred tax assets:
	Accrued pension and other postretirement costs		1,306			458			1,155			364
	Regulatory liabilities		615			604			574			569
	Superfund and other environmental costs		306			301			264			256
	Asset retirement obligations		77			58			75			58
	Loss carryforwards		21			12			-			-
	Loss carryforwards, valuation reserve		(11	)		(12	)		-			-
	Other		272			253			203			209
	Total deferred tax assets		2,586			1,674			2,271			1,456
	Net deferred tax liabilities and investment tax credits	$	8,948		$	8,344		$	8,163		$	7,732
	Deferred income taxes and investment tax credits – noncurrent	$	9,076		$	8,466		$	8,257		$	7,832
	Deferred tax assets – current		(128	)		(122	)		(94	)		(100	)
	Net deferred tax liabilities and investment tax credits	$	8,948		$	8,344		$	8,163		$	7,732
	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)	2014			2013			2012			2014			2013			2012
	STATUTORY TAX RATE
	Federal		35	%		35	%		35	%		35	%		35	%		35	%
	Changes in computed taxes resulting from:
	State income tax		5			4			4			5			5			4
	Cost of removal		(5	)		(5	)		(4	)		(5	)		(5	)		(4	)
	Manufacturing deduction		-			(1	)		-			-			-			-
	Other		(1	)		(2	)		(1	)		(1	)		(1	)		(1	)
	Effective tax rate		34	%		31	%		34	%		34	%		34	%		34	%
	Con Edison has a net operating loss carryforward available from the years 1999 through 2014 for which a deferred tax asset of $21 million has been recognized and will not expire until the years 2019 through 2034. An $11 million valuation allowance for New York City income tax purpose has been provided; as it is not more likely than not that the deferred tax asset will be realized.
	In September 2013, the IRS issued final regulations, effective in 2014, that provide guidance on the appropriate tax treatment of costs incurred to acquire, produce or improve tangible property, as well as routine maintenance and repair costs. Proposed regulations were issued addressing the tax treatment of asset dispositions. The application of these regulations did not have a material impact on the Companies’ financial position, results of operations or liquidity.
	In March 2014, tax legislation was enacted in the State of New York that reduced the corporate franchise tax rate from 7.1 percent to 6.5 percent, beginning January 1, 2016. The application of this legislation decreased Con Edison’s accumulated deferred tax liabilities by $74 million ($69 million for CECONY), decreased Con Edison’s regulatory asset for future income tax by $11 million ($10 million for CECONY) and increased Con Edison’s regulatory liability by $62 million ($59 million for CECONY). The impact of this tax legislation on Con Edison’s effective tax rate was not material, and there was no impact on CECONY’s effective tax rate for the year ended December 31, 2014.
	Under the Taxpayer Relief Act of 2012, 50 percent bonus depreciation expired on December 31, 2013. On December 19, 2014, President Obama signed into law the Tax Increase Prevention Act of 2014, which extended bonus depreciation for another year through December 31, 2014. As a result of the extension of bonus depreciation to 2014, Con Edison filed a refund request with the IRS in January 2015 to recover $224 million ($128 million attributable to CECONY) in estimated federal tax payments.
	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.
	In 2014 following the conclusion of its IRS audit, Con Edison filed amended state tax returns (primarily New York) for tax years 1998 through 2011. As a result of positions taken on the amended state tax returns, Con Edison increased its estimated liabilities for uncertain tax positions by $27 million ($2 million attributable to CECONY). The amended returns contain uncertain tax positions unique to the states, and the returns remain open for examination. The federal tax returns for 2011 through 2013 remain open for examination. These changes to the Companies’ estimated liabilities for uncertain tax positions had an immaterial impact on income tax expense for the year ended December 31, 2014.
	A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows:
		Con Edison									CECONY
	(Millions of Dollars)	2014			2013			2012			2014			2013			2012
	Balance at January 1,	$	9		$	86		$	130		$	-		$	74		$	114
	Additions based on tax positions related to the current year		-			5			12			-			-			11
	Additions based on tax positions of prior years		27			253			-			2			-			-
	Reductions for tax positions of prior years		(2	)		(86	)		(57	)		-			(74	)		(52	)
	Settlements		-			(249	)		1			-			-			1
Balance at December 31,	$	34		$	9		$	86		$	2		$	-		$	74
As of December 31, 2014, Con Edison reasonably expects to resolve approximately $26 million ($17 million, net of federal taxes) of its uncertainties related to certain tax matters within the next twelve months. Favorable resolution would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $2 million ($1 million, net of federal taxes), of which the entire amount, if recognized, would reduce CECONY’s effective tax rate.
The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In 2014 and 2012, the Companies recognized an immaterial amount of interest and no penalties for uncertain tax positions in their consolidated income statements. In 2013, Con Edison recognized $121 million of interest expense ($131 million related to the LILO transactions (see “Lease In/Lease Out Transactions” in Note J), less a reduction of $10 million in accrued interest expense primarily associated with repair allowance deductions and reversing other uncertain tax positions in 2013). At December 31, 2014 and 2013, the Companies recognized an immaterial amount of interest and no penalties in their consolidated balance sheets.
At December 31, 2014, the total amount of unrecognized tax benefits that, if recognized, would reduce the Companies’ effective tax rate is $34 million ($22 million, net of federal taxes) with $2 million ($1 million, net of federal taxes) attributable to CECONY.

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2014
Stock-Based Compensation	Note M – 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 (authorized, but unissued) shares, treasury shares or shares purchased in the open market. The Companies intend to use treasury shares and new shares to fulfill their stock-based compensation obligations for 2015.
	Under the accounting rules for stock compensation, the Companies have recognized the cost of stock-based compensation as an 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, 2014, 2013 and 2012:
			Con Edison								CECONY
	(Millions of Dollars)		2014			2013		2012			2014			2013		2012
	Performance-based restricted stock		$	22		$	20	$	14		$	19		$	18	$	13
	Time-based restricted stock			2			2		1			2			2		1
	Non-employee director deferred stock compensation			2			2		1			2			2		1
	Stock purchase plan			3			3		3			3			3		3
	Total		$	29		$	27	$	19		$	26		$	25	$	18
	Income tax benefit		$	12		$	11	$	8		$	10		$	10	$	7
	Stock Options
	The Companies last granted stock options in 2006. The stock options generally vested over a three-year period and have a term of 10 years. Options were granted at an exercise price equal to the fair market value of a common share when the option was granted. The Companies generally recognized compensation expense (based on the fair value of stock option awards) over the vesting period.
	The outstanding options are “equity awards” because shares of Con Edison common stock are delivered upon exercise of the options. As equity awards, the fair value of the options is measured at the grant date.
	A summary of changes in the status of stock options as of December 31, 2014 is as follows:
			Con Edison								CECONY
			Shares			Weighted		Shares			Weighted
						Average					Average
						Exercise					Exercise
						Price					Price
	Outstanding at 12/31/13			481,310		$	43.38		381,010		$	43.34
	Exercised			(251,460	)		43.75		(189,660	)		43.68
	Forfeited			-			-		-			-
	Outstanding at 12/31/14			229,850		$	42.99		191,350		$	43
	Note: The weighted average remaining contractual life is one year for all outstanding options as of 12/31/14.
	The following table summarizes information about stock options for the years ended December 31, 2014 and 2013:
			Con Edison					CECONY
	(Millions of Dollars)		2014			2013		2014			2013
	Aggregate intrinsic value*
	Options outstanding		$	5		$	6	$	4		$	5
	Options exercised			4			2		3			2
	Cash received by Con Edison for			11			5		8			4
	payment of exercise price
	*	Aggregate intrinsic value represents the changes in the fair value of all outstanding options from their grant dates to December 31 of the years presented above.
	The income tax benefit Con Edison realized from stock options exercised in the years ended December 31, 2014, 2013 and 2012 was $1 million, $10 million and an immaterial amount, respectively.
	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 represents 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 a factor that may range from 0 to 120 percent for management employees and 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 multiplied by 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 following table illustrates the assumptions used to calculate the fair value of the awards:
			2014			2013		2012
	Risk-free interest rate(a)			0.23% - 3.07%			0.13% - 5.17%		0.15% - 3.39%
	Expected term(b)			3 years			3 years		3 years
	Expected share price volatility(c)			13.14%			13.52%		15.27%
	(a)	The risk-free rate is based on the U.S. Treasury zero-coupon yield curve on the date of grant.
	(b)	The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur.
	(c)	The expected volatility is calculated using daily closing stock prices over a period of three years, which approximates the expected term of the awards.
	A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2014 is as follows:
			Con Edison								CECONY
			Units			Weighted					Units			Weighted
						Average								Average
						Grant Date								Grant Date
						Fair Value(a)								Fair Value(a)
						TSR		Non-TSR						TSR		Non-TSR
						Portion(b)		Portion(c)						Portion(b)		Portion(c)
	Non-vested at 12/31/13			1,121,598		$	49.32	$	55.31			897,052		$	49.38	$	55.42
	Granted			428,310			25.34		53.65			342,001			25.86		53.71
	Vested			(411,704	)		43.84		50.05			(323,483	)		43.93		50.08
	Forfeited			(37,597	)		40.9		55.97			(35,047	)		40.84		55.95
	Non-vested at 12/31/14			1,100,607		$	42.33	$	56.61			880,523		$	42.58	$	56.7
	(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 as of December 31, 2014 is $25 million, including $19 million for CECONY and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY.
In accordance with the accounting rules for stock compensation, for time-based awards, the Companies have accrued a liability based on the market value of a common share on the grant date and are recognizing compensation expense over 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, 2014 is as follows:
		Con Edison					CECONY
		Units			Weighted		Units			Weighted
					Average					Average
					Grant					Grant
					Date Fair					Date Fair
					Value					Value
Non-vested at 12/31/13			66,580		$	56.92		63,030		$	56.93
Granted			22,990			53.65		21,790			53.65
Vested			(20,900	)		50.74		(19,800	)		50.75
Forfeited			(3,247	)		58.06		(2,847	)		58.27
Non-vested at 12/31/14			65,423		$	57.65		62,173		$	57.64
The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding as of December 31, 2014 for Con Edison was $2 million, including $2 million for CECONY, and is expected to be recognized over a weighted average period of one year.
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, 2014, approximately 37,972 units were issued at a weighted average grant date price of $55.51.
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. 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 2014, 2013 and 2012, 708,276, 864,281 and 665,718 shares were purchased under the Stock Purchase Plan at a weighted average price of $56.23, $57.24 and $59.72 per share, respectively.
CECONY [Member]
Stock-Based Compensation	Note M – 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 (authorized, but unissued) shares, treasury shares or shares purchased in the open market. The Companies intend to use treasury shares and new shares to fulfill their stock-based compensation obligations for 2015.
	Under the accounting rules for stock compensation, the Companies have recognized the cost of stock-based compensation as an 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, 2014, 2013 and 2012:
			Con Edison								CECONY
	(Millions of Dollars)		2014			2013		2012			2014			2013		2012
	Performance-based restricted stock		$	22		$	20	$	14		$	19		$	18	$	13
	Time-based restricted stock			2			2		1			2			2		1
	Non-employee director deferred stock compensation			2			2		1			2			2		1
	Stock purchase plan			3			3		3			3			3		3
	Total		$	29		$	27	$	19		$	26		$	25	$	18
	Income tax benefit		$	12		$	11	$	8		$	10		$	10	$	7
	Stock Options
	The Companies last granted stock options in 2006. The stock options generally vested over a three-year period and have a term of 10 years. Options were granted at an exercise price equal to the fair market value of a common share when the option was granted. The Companies generally recognized compensation expense (based on the fair value of stock option awards) over the vesting period.
	The outstanding options are “equity awards” because shares of Con Edison common stock are delivered upon exercise of the options. As equity awards, the fair value of the options is measured at the grant date.
	A summary of changes in the status of stock options as of December 31, 2014 is as follows:
			Con Edison								CECONY
			Shares			Weighted		Shares			Weighted
						Average					Average
						Exercise					Exercise
						Price					Price
	Outstanding at 12/31/13			481,310		$	43.38		381,010		$	43.34
	Exercised			(251,460	)		43.75		(189,660	)		43.68
	Forfeited			-			-		-			-
	Outstanding at 12/31/14			229,850		$	42.99		191,350		$	43
	Note: The weighted average remaining contractual life is one year for all outstanding options as of 12/31/14.
	The following table summarizes information about stock options for the years ended December 31, 2014 and 2013:
			Con Edison					CECONY
	(Millions of Dollars)		2014			2013		2014			2013
	Aggregate intrinsic value*
	Options outstanding		$	5		$	6	$	4		$	5
	Options exercised			4			2		3			2
	Cash received by Con Edison for			11			5		8			4
	payment of exercise price
	*	Aggregate intrinsic value represents the changes in the fair value of all outstanding options from their grant dates to December 31 of the years presented above.
	The income tax benefit Con Edison realized from stock options exercised in the years ended December 31, 2014, 2013 and 2012 was $1 million, $10 million and an immaterial amount, respectively.
	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 represents 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 a factor that may range from 0 to 120 percent for management employees and 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 multiplied by 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 following table illustrates the assumptions used to calculate the fair value of the awards:
			2014			2013		2012
	Risk-free interest rate(a)			0.23% - 3.07%			0.13% - 5.17%		0.15% - 3.39%
	Expected term(b)			3 years			3 years		3 years
	Expected share price volatility(c)			13.14%			13.52%		15.27%
	(a)	The risk-free rate is based on the U.S. Treasury zero-coupon yield curve on the date of grant.
	(b)	The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur.
	(c)	The expected volatility is calculated using daily closing stock prices over a period of three years, which approximates the expected term of the awards.
	A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2014 is as follows:
			Con Edison								CECONY
			Units			Weighted					Units			Weighted
						Average								Average
						Grant Date								Grant Date
						Fair Value(a)								Fair Value(a)
						TSR		Non-TSR						TSR		Non-TSR
						Portion(b)		Portion(c)						Portion(b)		Portion(c)
	Non-vested at 12/31/13			1,121,598		$	49.32	$	55.31			897,052		$	49.38	$	55.42
	Granted			428,310			25.34		53.65			342,001			25.86		53.71
	Vested			(411,704	)		43.84		50.05			(323,483	)		43.93		50.08
	Forfeited			(37,597	)		40.9		55.97			(35,047	)		40.84		55.95
	Non-vested at 12/31/14			1,100,607		$	42.33	$	56.61			880,523		$	42.58	$	56.7
	(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 as of December 31, 2014 is $25 million, including $19 million for CECONY and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY.
In accordance with the accounting rules for stock compensation, for time-based awards, the Companies have accrued a liability based on the market value of a common share on the grant date and are recognizing compensation expense over 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, 2014 is as follows:
		Con Edison					CECONY
		Units			Weighted		Units			Weighted
					Average					Average
					Grant					Grant
					Date Fair					Date Fair
					Value					Value
Non-vested at 12/31/13			66,580		$	56.92		63,030		$	56.93
Granted			22,990			53.65		21,790			53.65
Vested			(20,900	)		50.74		(19,800	)		50.75
Forfeited			(3,247	)		58.06		(2,847	)		58.27
Non-vested at 12/31/14			65,423		$	57.65		62,173		$	57.64
The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding as of December 31, 2014 for Con Edison was $2 million, including $2 million for CECONY, and is expected to be recognized over a weighted average period of one year.
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, 2014, approximately 37,972 units were issued at a weighted average grant date price of $55.51.
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. 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 2014, 2013 and 2012, 708,276, 864,281 and 665,718 shares were purchased under the Stock Purchase Plan at a weighted average price of $56.23, $57.24 and $59.72 per share, respectively.

Financial_Information_by_Busin

Financial Information by Business Segment	12 Months Ended
	Dec. 31, 2014
Financial Information by Business Segment	Note N – 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 and Con Edison’s competitive energy businesses. 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		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2014		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,437		$	16		$	781		$	1,712		$	412		$	425		$	30,421	$	1,500
	Gas			1,721			6			132			314			89			88			6,530		549
	Steam			628			84			78			113			36			49			2,686		83
	Consolidation adjustments			-			(106	)		-			-			-			-			-		-
	Total CECONY		$	10,786		$	-		$	991		$	2,139		$	537		$	562		$	39,637	$	2,132
	O&R
	Electric		$	680		$	-		$	46		$	103		$	24		$	29		$	2,042	$	105
	Gas			212			-			15			25			10			6			794		37
	Other(b)			-			-			-			-			1			-			1		-
	Total O&R		$	892		$	-		$	61		$	128		$	35		$	35		$	2,837	$	142
	Competitive energy businesses		$	1,244		$	(10	)	$	19		$	(60	)	$	(8	)	$	(8	)	$	1,026	$	447
	Other(c)			(3	)		10			-			2			27			-			808		-
	Total Con Edison		$	12,919		$	-		$	1,071		$	2,209		$	591		$	589		$	44,308	$	2,721
	As of and for the Year Ended		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2013		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,131		$	16		$	749		$	1,595		$	402		$	380		$	27,673	$	1,471
	Gas			1,616			5			130			362			83			112			6,008		536
	Steam			683			82			67			103			36			39			2,577		128
	Consolidation adjustments			-			(103	)		-			-			-			-			-		-
	Total CECONY		$	10,430		$	-		$	946		$	2,060		$	521		$	531		$	36,258	$	2,135
	O&R
	Electric		$	628		$	-		$	41		$	87		$	25		$	13		$	1,898	$	98
	Gas			205			-			15			33			11			7			645		37
	Other(b)			-			-			-			-			1			-			2		-
	Total O&R		$	833		$	-		$	56		$	120		$	37		$	20		$	2,545	$	135
	Competitive energy businesses		$	1,096		$	5		$	23		$	63		$	135		$	(41	)	$	1,314	$	378
	Other(c)			(5	)		(5	)		(1	)		1			26			(6	)		530		-
	Total Con Edison		$	12,354		$	-		$	1,024		$	2,244		$	719		$	504		$	40,647	$	2,648
	As of and for the Year Ended		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2012		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,176		$	15		$	710		$	1,693		$	423		$	393		$	28,339	$	1,375
	Gas			1,415			5			120			346			82			99			5,925		426
	Steam			596			77			64			54			40			22			2,621		108
	Consolidation adjustments			-			(97	)		-			-			-			-			-		-
	Total CECONY		$	10,187		$	-		$	894		$	2,093		$	545		$	514		$	36,885	$	1,909
	O&R
	Electric		$	592		$	-		$	38		$	83		$	19		$	17		$	1,960	$	98
	Gas			203			-			15			40			10			11			706		39
	Other(b)			-			-			-			-			2			-			5		-
	Total O&R		$	795		$	-		$	53		$	123		$	31		$	28		$	2,671	$	137
	Competitive energy businesses		$	1,213		$	8		$	8		$	125		$	1		$	52		$	1,061	$	492
	Other(c)			(7	)		(8	)		-			(2	)		27			-			592		-
	Total Con Edison		$	12,188		$	-		$	955		$	2,339		$	604		$	594		$	41,209	$	2,538
	(a)	For Con Edison, income taxes on non-operating income were $(21), $(28) and $6 million in 2014, 2013 and 2012, respectively. For CECONY, income taxes on non-operating income were $(7), $(11) and $15 million in 2014, 2013 and 2012, respectively.
	(b)	Includes amounts related to the RECO securitization.
	(c)	Parent company and consolidation adjustments. Other does not represent a business segment.
CECONY [Member]
Financial Information by Business Segment	Note N – 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 and Con Edison’s competitive energy businesses. 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		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2014		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,437		$	16		$	781		$	1,712		$	412		$	425		$	30,421	$	1,500
	Gas			1,721			6			132			314			89			88			6,530		549
	Steam			628			84			78			113			36			49			2,686		83
	Consolidation adjustments			-			(106	)		-			-			-			-			-		-
	Total CECONY		$	10,786		$	-		$	991		$	2,139		$	537		$	562		$	39,637	$	2,132
	O&R
	Electric		$	680		$	-		$	46		$	103		$	24		$	29		$	2,042	$	105
	Gas			212			-			15			25			10			6			794		37
	Other(b)			-			-			-			-			1			-			1		-
	Total O&R		$	892		$	-		$	61		$	128		$	35		$	35		$	2,837	$	142
	Competitive energy businesses		$	1,244		$	(10	)	$	19		$	(60	)	$	(8	)	$	(8	)	$	1,026	$	447
	Other(c)			(3	)		10			-			2			27			-			808		-
	Total Con Edison		$	12,919		$	-		$	1,071		$	2,209		$	591		$	589		$	44,308	$	2,721
	As of and for the Year Ended		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2013		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,131		$	16		$	749		$	1,595		$	402		$	380		$	27,673	$	1,471
	Gas			1,616			5			130			362			83			112			6,008		536
	Steam			683			82			67			103			36			39			2,577		128
	Consolidation adjustments			-			(103	)		-			-			-			-			-		-
	Total CECONY		$	10,430		$	-		$	946		$	2,060		$	521		$	531		$	36,258	$	2,135
	O&R
	Electric		$	628		$	-		$	41		$	87		$	25		$	13		$	1,898	$	98
	Gas			205			-			15			33			11			7			645		37
	Other(b)			-			-			-			-			1			-			2		-
	Total O&R		$	833		$	-		$	56		$	120		$	37		$	20		$	2,545	$	135
	Competitive energy businesses		$	1,096		$	5		$	23		$	63		$	135		$	(41	)	$	1,314	$	378
	Other(c)			(5	)		(5	)		(1	)		1			26			(6	)		530		-
	Total Con Edison		$	12,354		$	-		$	1,024		$	2,244		$	719		$	504		$	40,647	$	2,648
	As of and for the Year Ended		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2012		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,176		$	15		$	710		$	1,693		$	423		$	393		$	28,339	$	1,375
	Gas			1,415			5			120			346			82			99			5,925		426
	Steam			596			77			64			54			40			22			2,621		108
	Consolidation adjustments			-			(97	)		-			-			-			-			-		-
	Total CECONY		$	10,187		$	-		$	894		$	2,093		$	545		$	514		$	36,885	$	1,909
	O&R
	Electric		$	592		$	-		$	38		$	83		$	19		$	17		$	1,960	$	98
	Gas			203			-			15			40			10			11			706		39
	Other(b)			-			-			-			-			2			-			5		-
	Total O&R		$	795		$	-		$	53		$	123		$	31		$	28		$	2,671	$	137
	Competitive energy businesses		$	1,213		$	8		$	8		$	125		$	1		$	52		$	1,061	$	492
	Other(c)			(7	)		(8	)		-			(2	)		27			-			592		-
	Total Con Edison		$	12,188		$	-		$	955		$	2,339		$	604		$	594		$	41,209	$	2,538
	(a)	For Con Edison, income taxes on non-operating income were $(21), $(28) and $6 million in 2014, 2013 and 2012, respectively. For CECONY, income taxes on non-operating income were $(7), $(11) and $15 million in 2014, 2013 and 2012, respectively.
	(b)	Includes amounts related to the RECO securitization.
	(c)	Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities	Note O – Derivative Instruments and Hedging Activities
	Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas and steam by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the balance sheet at fair value (See Note P), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules.
	The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at December 31, 2014 and 2013 were:
	(Millions of Dollars)		2014												2013
	Balance Sheet Location		Gross				Gross				Net Amounts				Gross				Gross			Net Amounts
			Amounts of				Amounts				of Assets/				Amounts of				Amounts			of Assets/
			Recognized				Offset				(Liabilities)(a)				Recognized				Offset			(Liabilities)(a)
			Assets/												Assets/
			(Liabilities)												(Liabilities)
	Con Edison
	Fair value of derivative assets
	Current		$	111			$	(67	)		$	44	(b)		$	134			$	(77	)	$	57	(b)
	Non-current			34				(23	)			11				32				(24	)		8
	Total fair value of derivative assets		$	145			$	(90	)		$	55			$	166			$	(101	)	$	65
	Fair value of derivative liabilities
	Current		$	(242	)		$	139			$	(103	)		$	(82	)		$	72		$	(10	)
	Non-current			(66	)			91				25				(31	)			26			(5	)
	Total fair value of derivative liabilities		$	(308	)		$	230			$	(78	)		$	(113	)		$	98		$	(15	)
	Net fair value derivative assets/(liabilities)		$	(163	)		$	140			$	(23	)(b)		$	53			$	(3	)	$	50	(b)
	CECONY
	Fair value of derivative assets
	Current		$	26			$	(15	)		$	11	(b)		$	27			$	(19	)	$	8	(b)
	Non-current			22				(20	)			2				14				(13	)		1
	Total fair value of derivative assets		$	48			$	(35	)		$	13			$	41			$	(32	)	$	9
	Fair value of derivative liabilities
	Current		$	(96	)		$	48			$	(48	)		$	(32	)		$	21		$	(11	)
	Non-current liabilities			(42	)			32				(10	)			(19	)			16			(3	)
	Total fair value of derivative liabilities		$	(138	)		$	80			$	(58	)		$	(51	)		$	37		$	(14	)
	Net fair value derivative assets/(liabilities)		$	(90	)		$	45			$	(45	)(b)		$	(10	)		$	5		$	(5	)(b)
	(a)	Derivative instruments and collateral were set off 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 setoff in the event of contract termination. In such case, generally the non-defaulting party’s payable will be set-off 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, 2014 and 2013, margin deposits for Con Edison ($27 million and $17 million, respectively) and CECONY ($25 million and $16 million, respectively) were classified as derivative assets in the 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.
	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. Con Edison’s competitive energy businesses record realized and unrealized gains and losses on their derivative contracts in purchased power, gas purchased for resale and non-utility revenue in the reporting period in which they occur. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.
	The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the years ended December 31, 2014 and 2013:
					Con Edison								CECONY
	(Millions of Dollars)		Balance Sheet Location		2014				2013				2014				2013
	Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
	Current		Deferred derivative gains		$	(10	)		$	14			$	(7	)		$	11
	Long-term		Deferred derivative gains			1				-				1				-
	Total deferred gains/(losses)				$	(9	)		$	14			$	(6	)		$	11
	Current		Deferred derivative losses		$	(75	)		$	47			$	(70	)		$	38
	Current		Recoverable energy costs			36				(39	)			26				(37	)
	Long-term		Deferred derivative losses			(17	)			27				(17	)			13
	Total deferred gains/(losses)				$	(56	)		$	35			$	(61	)		$	14
	Net deferred gains/(losses)				$	(65	)		$	49			$	(67	)		$	25
			Income Statement Location
	Pre-tax gain/(loss) recognized in income
			Purchased power expense		$	(37	)(a)		$	90	(a)		$	-			$	-
			Gas purchased for resale			(115	)			(27	)			-				-
			Non-utility revenue			29	(a)			9	(a)			-				-
	Total pre-tax gain/(loss) recognized in income				$	(123	)		$	72			$	-			$	-
	(a)	Con Edison recorded unrealized gains and losses in non-utility operating revenue ($4 million gain and an immaterial gain) and purchased power expense ($132 million loss and $74 million gain) for the years ended December 31, 2014 and 2013, respectively.
	The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at December 31, 2014:
			Electric Energy (MWHs)(a)(b)				Capacity (MWs)(a)				Natural Gas (Dt)(a)(b)
	Con Edison			17,792,555				7,706				66,793,011
	CECONY			5,543,250				2,100				62,065,000
	(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 competitive 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 of setoff.
	At December 31, 2014, Con Edison and CECONY had $148 million and $25 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $79 million with commodity exchange brokers, $45 million with independent system operators, $20 million with investment-grade counterparties and $4 million with non-investment grade/non-rated counterparties. CECONY’s net credit exposure was 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, 2014:
	(Millions of Dollars)		Con Edison(a)				CECONY(a)
	Aggregate fair value – net liabilities		$	78			$	58
	Collateral posted		$	1			$	-
Additional collateral(b) (downgrade one level from current ratings)		$	6			$	2
Additional collateral(b) (downgrade to below investment grade from current ratings)		$	105	(c)		$	63	(c)
(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 Con Edison’s competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post collateral, which at December 31, 2014, would have amounted to an estimated $16 million for Con Edison, including $3 million for CECONY. 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 liabilities 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 of setoff.
(c)	Derivative instruments that are net assets have been excluded from the table. At December 31, 2014, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $15 million.
CECONY [Member]
Derivative Instruments and Hedging Activities	Note O – Derivative Instruments and Hedging Activities
	Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas and steam by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the balance sheet at fair value (See Note P), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules.
	The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at December 31, 2014 and 2013 were:
	(Millions of Dollars)		2014												2013
	Balance Sheet Location		Gross				Gross				Net Amounts				Gross				Gross			Net Amounts
			Amounts of				Amounts				of Assets/				Amounts of				Amounts			of Assets/
			Recognized				Offset				(Liabilities)(a)				Recognized				Offset			(Liabilities)(a)
			Assets/												Assets/
			(Liabilities)												(Liabilities)
	Con Edison
	Fair value of derivative assets
	Current		$	111			$	(67	)		$	44	(b)		$	134			$	(77	)	$	57	(b)
	Non-current			34				(23	)			11				32				(24	)		8
	Total fair value of derivative assets		$	145			$	(90	)		$	55			$	166			$	(101	)	$	65
	Fair value of derivative liabilities
	Current		$	(242	)		$	139			$	(103	)		$	(82	)		$	72		$	(10	)
	Non-current			(66	)			91				25				(31	)			26			(5	)
	Total fair value of derivative liabilities		$	(308	)		$	230			$	(78	)		$	(113	)		$	98		$	(15	)
	Net fair value derivative assets/(liabilities)		$	(163	)		$	140			$	(23	)(b)		$	53			$	(3	)	$	50	(b)
	CECONY
	Fair value of derivative assets
	Current		$	26			$	(15	)		$	11	(b)		$	27			$	(19	)	$	8	(b)
	Non-current			22				(20	)			2				14				(13	)		1
	Total fair value of derivative assets		$	48			$	(35	)		$	13			$	41			$	(32	)	$	9
	Fair value of derivative liabilities
	Current		$	(96	)		$	48			$	(48	)		$	(32	)		$	21		$	(11	)
	Non-current liabilities			(42	)			32				(10	)			(19	)			16			(3	)
	Total fair value of derivative liabilities		$	(138	)		$	80			$	(58	)		$	(51	)		$	37		$	(14	)
	Net fair value derivative assets/(liabilities)		$	(90	)		$	45			$	(45	)(b)		$	(10	)		$	5		$	(5	)(b)
	(a)	Derivative instruments and collateral were set off 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 setoff in the event of contract termination. In such case, generally the non-defaulting party’s payable will be set-off 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, 2014 and 2013, margin deposits for Con Edison ($27 million and $17 million, respectively) and CECONY ($25 million and $16 million, respectively) were classified as derivative assets in the 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.
	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. Con Edison’s competitive energy businesses record realized and unrealized gains and losses on their derivative contracts in purchased power, gas purchased for resale and non-utility revenue in the reporting period in which they occur. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.
	The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the years ended December 31, 2014 and 2013:
					Con Edison								CECONY
	(Millions of Dollars)		Balance Sheet Location		2014				2013				2014				2013
	Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
	Current		Deferred derivative gains		$	(10	)		$	14			$	(7	)		$	11
	Long-term		Deferred derivative gains			1				-				1				-
	Total deferred gains/(losses)				$	(9	)		$	14			$	(6	)		$	11
	Current		Deferred derivative losses		$	(75	)		$	47			$	(70	)		$	38
	Current		Recoverable energy costs			36				(39	)			26				(37	)
	Long-term		Deferred derivative losses			(17	)			27				(17	)			13
	Total deferred gains/(losses)				$	(56	)		$	35			$	(61	)		$	14
	Net deferred gains/(losses)				$	(65	)		$	49			$	(67	)		$	25
			Income Statement Location
	Pre-tax gain/(loss) recognized in income
			Purchased power expense		$	(37	)(a)		$	90	(a)		$	-			$	-
			Gas purchased for resale			(115	)			(27	)			-				-
			Non-utility revenue			29	(a)			9	(a)			-				-
	Total pre-tax gain/(loss) recognized in income				$	(123	)		$	72			$	-			$	-
	(a)	Con Edison recorded unrealized gains and losses in non-utility operating revenue ($4 million gain and an immaterial gain) and purchased power expense ($132 million loss and $74 million gain) for the years ended December 31, 2014 and 2013, respectively.
	The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at December 31, 2014:
			Electric Energy (MWHs)(a)(b)				Capacity (MWs)(a)				Natural Gas (Dt)(a)(b)
	Con Edison			17,792,555				7,706				66,793,011
	CECONY			5,543,250				2,100				62,065,000
	(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 competitive 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 of setoff.
	At December 31, 2014, Con Edison and CECONY had $148 million and $25 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $79 million with commodity exchange brokers, $45 million with independent system operators, $20 million with investment-grade counterparties and $4 million with non-investment grade/non-rated counterparties. CECONY’s net credit exposure was 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, 2014:
	(Millions of Dollars)		Con Edison(a)				CECONY(a)
	Aggregate fair value – net liabilities		$	78			$	58
	Collateral posted		$	1			$	-
Additional collateral(b) (downgrade one level from current ratings)		$	6			$	2
Additional collateral(b) (downgrade to below investment grade from current ratings)		$	105	(c)		$	63	(c)
(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 Con Edison’s competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post collateral, which at December 31, 2014, would have amounted to an estimated $16 million for Con Edison, including $3 million for CECONY. 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 liabilities 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 of setoff.
(c)	Derivative instruments that are net assets have been excluded from the table. At December 31, 2014, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $15 million.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Measurements	Note P – 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.
	Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2014 and 2013 are summarized below.
			2014														2013
	(Millions of Dollars)		Level 1			Level 2			Level 3			Netting			Total		Level 1		Level 2		Level 3		Netting			Total
												Adjustment(e)											Adjustment(e)
	Con Edison
	Derivative assets:
	Commodity(a)(b)(c)		$	3		$	78		$	28		$	(27	)	$	82	$	3	$	130	$	11	$	(62	)	$	82
	Other(a)(b)(d)			163			116			-			-			279		141		113		-		-			254
	Total assets		$	166		$	194		$	28		$	(27	)	$	361	$	144	$	243	$	11	$	(62	)	$	336
	Derivative liabilities:
	Commodity(a)(b)(c)		$	18		$	246		$	8		$	(194	)	$	78	$	5	$	84	$	2	$	(76	)	$	15
	Interest rate contract(a)(b)			-			-			-			-			-		-		2		-		-			2
	Total liabilities		$	18		$	246		$	8		$	(194	)	$	78	$	5	$	86	$	2	$	(76	)	$	17
	CECONY
	Derivative assets
	Commodity(a)(b)(c)		$	1		$	3		$	13		$	21		$	38	$	3	$	13	$	6	$	3		$	25
	Other(a)(b)(d)			155			106			-			-			261		134		103		-		-			237
	Total assets		$	156		$	109		$	13		$	21		$	299	$	137	$	116	$	6	$	3		$	262
	Derivative liabilities:
	Commodity(a)(b)(c)		$	16		$	91		$	-		$	(49	)	$	58	$	5	$	27	$	-	$	(18	)	$	14
	Total Liabilities		$	16		$	91		$	-		$	(49	)	$	58	$	5	$	27	$	-	$	(18	)	$	14
	(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. There were no transfers between levels 1, 2 and 3 for the years ended December 31, 2014 and 2013.
	(b)	Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, interest rate swap, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, and certain over-the-counter derivative instruments for electricity 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, 2014 and 2013, 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.
	The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives. Fair value and changes in fair value of commodity derivatives are reported 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 competitive energy businesses. The risk management group reports to the Companies’ Vice President and Treasurer.
			Fair Value of Level 3 at			Valuation		Unobservable Inputs	Range
			December 31, 2014			Techniques
			(Millions of Dollars)
	Con Edison – Commodity
	Electricity		$	1		Discounted Cash Flow		Forward energy prices(a)	$22.59 - $119.75 per MWH
						Discounted Cash Flow		Forward capacity prices(a)	$1.00 - $8.80 per kW -  month
	Natural Gas			2		Discounted Cash Flow		Forward gas prices(a)	$(1.64) - $5.00 per Dt
	Transmission Congestion Contracts / Financial Transmission Rights			17		Discounted Cash Flow		Discount to adjust auction prices for inter-zonal forward price curves(b)	9.6% - 57.9%
								Discount to adjust auction prices for historical monthly realized settlements(b)	32.3% - 56.1%
								Inter-zonal forward price curves adjusted for historical zonal losses(b)	$(2.66) - $16.49
	Total Con Edison—Commodity		$	20
	CECONY – Commodity
	Transmission Congestion Contracts		$	13		Discounted Cash Flow		Discount to adjust auction prices for inter-zonal forward price curves(b)	9.6% - 57.9%
								Discount to adjust auction prices for historical monthly realized settlements(b)	32.3% - 56.1%
	(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, 2014 and 2013 and classified as Level 3 in the fair value hierarchy:
			Con Edison						CECONY
	(Millions of Dollars)		2014			2013			2014			2013
	Beginning Balance as of January 1,		$	9		$	(5	)	$	6		$	10
	Included in Earnings			30			7			2			7
	Included in Regulatory Assets and Liabilities			7			18			7			(1	)
	Purchases			22			17			16			13
	Settlements			(48	)		(28	)		(18	)		(23	)
	Ending Balance as of December 31,		$	20		$	9		$	13		$	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 competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues (immaterial and $2 million loss) and purchased power costs ($27 million gain and $5 million gain) on the consolidated income statement for the years ended December 31, 2014 and 2013, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at December 31, 2014 and 2013 is included in non-utility revenues (immaterial and $2 million loss) and purchased power costs ($2 million gain and $3 million gain) on the consolidated income statement for the years ended December 31, 2014 and 2013, respectively.
CECONY [Member]
Fair Value Measurements	Note P – 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.
	Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2014 and 2013 are summarized below.
			2014														2013
	(Millions of Dollars)		Level 1			Level 2			Level 3			Netting			Total		Level 1		Level 2		Level 3		Netting			Total
												Adjustment(e)											Adjustment(e)
	Con Edison
	Derivative assets:
	Commodity(a)(b)(c)		$	3		$	78		$	28		$	(27	)	$	82	$	3	$	130	$	11	$	(62	)	$	82
	Other(a)(b)(d)			163			116			-			-			279		141		113		-		-			254
	Total assets		$	166		$	194		$	28		$	(27	)	$	361	$	144	$	243	$	11	$	(62	)	$	336
	Derivative liabilities:
	Commodity(a)(b)(c)		$	18		$	246		$	8		$	(194	)	$	78	$	5	$	84	$	2	$	(76	)	$	15
	Interest rate contract(a)(b)			-			-			-			-			-		-		2		-		-			2
	Total liabilities		$	18		$	246		$	8		$	(194	)	$	78	$	5	$	86	$	2	$	(76	)	$	17
	CECONY
	Derivative assets
	Commodity(a)(b)(c)		$	1		$	3		$	13		$	21		$	38	$	3	$	13	$	6	$	3		$	25
	Other(a)(b)(d)			155			106			-			-			261		134		103		-		-			237
	Total assets		$	156		$	109		$	13		$	21		$	299	$	137	$	116	$	6	$	3		$	262
	Derivative liabilities:
	Commodity(a)(b)(c)		$	16		$	91		$	-		$	(49	)	$	58	$	5	$	27	$	-	$	(18	)	$	14
	Total Liabilities		$	16		$	91		$	-		$	(49	)	$	58	$	5	$	27	$	-	$	(18	)	$	14
	(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. There were no transfers between levels 1, 2 and 3 for the years ended December 31, 2014 and 2013.
	(b)	Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, interest rate swap, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, and certain over-the-counter derivative instruments for electricity 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, 2014 and 2013, 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.
	The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives. Fair value and changes in fair value of commodity derivatives are reported 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 competitive energy businesses. The risk management group reports to the Companies’ Vice President and Treasurer.
			Fair Value of Level 3 at			Valuation		Unobservable Inputs	Range
			December 31, 2014			Techniques
			(Millions of Dollars)
	Con Edison – Commodity
	Electricity		$	1		Discounted Cash Flow		Forward energy prices(a)	$22.59 - $119.75 per MWH
						Discounted Cash Flow		Forward capacity prices(a)	$1.00 - $8.80 per kW -  month
	Natural Gas			2		Discounted Cash Flow		Forward gas prices(a)	$(1.64) - $5.00 per Dt
	Transmission Congestion Contracts / Financial Transmission Rights			17		Discounted Cash Flow		Discount to adjust auction prices for inter-zonal forward price curves(b)	9.6% - 57.9%
								Discount to adjust auction prices for historical monthly realized settlements(b)	32.3% - 56.1%
								Inter-zonal forward price curves adjusted for historical zonal losses(b)	$(2.66) - $16.49
	Total Con Edison—Commodity		$	20
	CECONY – Commodity
	Transmission Congestion Contracts		$	13		Discounted Cash Flow		Discount to adjust auction prices for inter-zonal forward price curves(b)	9.6% - 57.9%
								Discount to adjust auction prices for historical monthly realized settlements(b)	32.3% - 56.1%
	(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, 2014 and 2013 and classified as Level 3 in the fair value hierarchy:
			Con Edison						CECONY
	(Millions of Dollars)		2014			2013			2014			2013
	Beginning Balance as of January 1,		$	9		$	(5	)	$	6		$	10
	Included in Earnings			30			7			2			7
	Included in Regulatory Assets and Liabilities			7			18			7			(1	)
	Purchases			22			17			16			13
	Settlements			(48	)		(28	)		(18	)		(23	)
	Ending Balance as of December 31,		$	20		$	9		$	13		$	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 competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues (immaterial and $2 million loss) and purchased power costs ($27 million gain and $5 million gain) on the consolidated income statement for the years ended December 31, 2014 and 2013, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at December 31, 2014 and 2013 is included in non-utility revenues (immaterial and $2 million loss) and purchased power costs ($2 million gain and $3 million gain) on the consolidated income statement for the years ended December 31, 2014 and 2013, respectively.

Variable_Interest_Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2014
Variable Interest Entities	Note Q – 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.
	Con Edison enters into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, Con Edison retains or may retain a variable interest in these entities.
	CECONY
	CECONY has a variable interest in a non-consolidated VIE, Astoria Energy, LLC (Astoria Energy), with which CECONY has entered into a long-term electricity purchase agreement. CECONY is not the primary beneficiary of this VIE since CECONY does not have the power to direct activities that CECONY believes most significantly impact the economic performance of Astoria Energy. In particular, CECONY has not invested in, or guaranteed the indebtedness of, Astoria Energy and CECONY does not operate or maintain Astoria Energy’s generating facilities. CECONY also has long-term electricity purchase agreements with the following three potential VIEs: Cogen Technologies Linden Venture, LP, Brooklyn Navy Yard Cogeneration Partners, LP and Indeck Energy Services of Corinth, Inc. In 2014, requests were made of these three counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY’s maximum exposure to loss with respect to the potential VIEs.
	Con Edison Development
	Con Edison has a variable interest in Copper Mountain Solar 3 Holdings, LLC (Copper Mountain Solar 3), which is a non-consolidated entity in which Con Edison Development purchased a 50 percent membership interest in 2014. Copper Mountain Solar 3 owns a project company that is developing a 250 MW (AC) solar electric production project in Nevada. Electricity generated by the project is to be sold to the Southern California Public Power Authority pursuant to a long-term power purchase agreement. In addition, Con Edison and Con Edison Development have issued certain guarantees to third parties in connection with Copper Mountain Solar 3. See “Guarantees” in Note H.
	Con Edison has a variable interest in CED California Holdings Financing I, LLC (California Solar), which is no longer a consolidated entity. Con Edison Development sold 50 percent of its membership interest in California Solar which was previously a wholly-owned subsidiary in 2014. California Solar owns project companies that operate 110 MW (AC) of solar electric production projects in California. Electricity generated by the projects is sold to Pacific Gas and Electric Company pursuant to long-term power purchase agreements. Subsequent to the sale, Con Edison Development’s remaining 50 percent interest in California Solar is accounted for under the equity method.
	As a result of the sale, Con Edison Development received net proceeds of $108 million and recognized a pre-tax gain on the sale of $45 million ($26 million, net of tax). The following table summarizes the sale and resultant deconsolidation on the transaction date:
	(Millions of Dollars)
	Proceeds from sale, net of transaction costs of $1		$	108
	Non-utility property, less accumulated depreciation			(341	)
	Other assets, including working capital			(31	)
	Long-term debt, including current portion			217
	Other liabilities			9
	Gain on sale of solar electric production projects			(45	)
	Equity method investment upon deconsolidation		$	(83	)
	Con Edison has a variable interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), which is a consolidated entity in which Con Edison Development purchased an 80 percent membership interest in 2014 for $49 million. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project in Texas. Electricity generated by the project is sold to the City of San Antonio pursuant to a long-term power purchase agreement. At December 31, 2014, Con Edison’s consolidated balance sheet includes $58 million in net assets (as detailed in the table below) and the non-controlling interest of the third party of $9 million related to Texas Solar 4. Earnings for the twelve months ended December 31, 2014 were immaterial.
	(Millions of Dollars)
	Restricted cash		$	13
	Non-utility property, less accumulated depreciation			108
	Other assets			14
	Total assets(a)		$	135
	Long-term debt due within one year		$	66
	Other liabilities			11
	Total liabilities(b)		$	77
	(a)	The assets of Texas Solar 4 represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE.
	(b)	The liabilities of Texas Solar 4 represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary.
	Con Edison has a variable interest in Broken Bow II Wind Holdings, LLC (Broken Bow II), which is a non-consolidated entity in which Con Edison Development purchased a 50 percent membership interest in 2014. Broken Bow II owns a project company that developed a 75 MW (AC) wind electric production project in Nebraska. Electricity generated by the project is sold to Nebraska Public Power District pursuant to a long-term power purchase agreement.
	The following table summarizes the VIEs in which Con Edison Development has entered into as of December 31, 2014:
	Project Name(a)		Generating			Power Purchase			Year of Initial		Location		Maximum Exposure to
			Capacity			Agreement Term			Investment				Loss (In Millions)(c)
			Owned			in Years
	Pilesgrove			9			n/a	(b)		2010		New Jersey	$	26
	Mesquite Solar 1			83			20			2013		Arizona		111
	Copper Mountain Solar 2			75			25			2013		Nevada		80
	Copper Mountain Solar 3			128			20			2014		Nevada		175
	California Solar			55			25			2012		California		81
	Texas Solar 4			32			25			2014		Texas		58
	Broken Bow II			37			25			2014		Nebraska		57
	(a)	With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development.
	(b)	Pilesgrove has 3-5 year Solar Renewable Energy Credit (SREC) hedges in place.
	(c)	For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the balance sheet. For consolidated investments, maximum exposure is equal to the net assets of the investment on the balance sheet. Con Edison did not provide any financial or other support during the year that was not previously contractually required.
CECONY [Member]
Variable Interest Entities	Note Q – 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.
	Con Edison enters into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, Con Edison retains or may retain a variable interest in these entities.
	CECONY
	CECONY has a variable interest in a non-consolidated VIE, Astoria Energy, LLC (Astoria Energy), with which CECONY has entered into a long-term electricity purchase agreement. CECONY is not the primary beneficiary of this VIE since CECONY does not have the power to direct activities that CECONY believes most significantly impact the economic performance of Astoria Energy. In particular, CECONY has not invested in, or guaranteed the indebtedness of, Astoria Energy and CECONY does not operate or maintain Astoria Energy’s generating facilities. CECONY also has long-term electricity purchase agreements with the following three potential VIEs: Cogen Technologies Linden Venture, LP, Brooklyn Navy Yard Cogeneration Partners, LP and Indeck Energy Services of Corinth, Inc. In 2014, requests were made of these three counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY’s maximum exposure to loss with respect to the potential VIEs.
	Con Edison Development
	Con Edison has a variable interest in Copper Mountain Solar 3 Holdings, LLC (Copper Mountain Solar 3), which is a non-consolidated entity in which Con Edison Development purchased a 50 percent membership interest in 2014. Copper Mountain Solar 3 owns a project company that is developing a 250 MW (AC) solar electric production project in Nevada. Electricity generated by the project is to be sold to the Southern California Public Power Authority pursuant to a long-term power purchase agreement. In addition, Con Edison and Con Edison Development have issued certain guarantees to third parties in connection with Copper Mountain Solar 3. See “Guarantees” in Note H.
	Con Edison has a variable interest in CED California Holdings Financing I, LLC (California Solar), which is no longer a consolidated entity. Con Edison Development sold 50 percent of its membership interest in California Solar which was previously a wholly-owned subsidiary in 2014. California Solar owns project companies that operate 110 MW (AC) of solar electric production projects in California. Electricity generated by the projects is sold to Pacific Gas and Electric Company pursuant to long-term power purchase agreements. Subsequent to the sale, Con Edison Development’s remaining 50 percent interest in California Solar is accounted for under the equity method.
	As a result of the sale, Con Edison Development received net proceeds of $108 million and recognized a pre-tax gain on the sale of $45 million ($26 million, net of tax). The following table summarizes the sale and resultant deconsolidation on the transaction date:
	(Millions of Dollars)
	Proceeds from sale, net of transaction costs of $1		$	108
	Non-utility property, less accumulated depreciation			(341	)
	Other assets, including working capital			(31	)
	Long-term debt, including current portion			217
	Other liabilities			9
	Gain on sale of solar electric production projects			(45	)
	Equity method investment upon deconsolidation		$	(83	)
	Con Edison has a variable interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), which is a consolidated entity in which Con Edison Development purchased an 80 percent membership interest in 2014 for $49 million. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project in Texas. Electricity generated by the project is sold to the City of San Antonio pursuant to a long-term power purchase agreement. At December 31, 2014, Con Edison’s consolidated balance sheet includes $58 million in net assets (as detailed in the table below) and the non-controlling interest of the third party of $9 million related to Texas Solar 4. Earnings for the twelve months ended December 31, 2014 were immaterial.
	(Millions of Dollars)
	Restricted cash		$	13
	Non-utility property, less accumulated depreciation			108
	Other assets			14
	Total assets(a)		$	135
	Long-term debt due within one year		$	66
	Other liabilities			11
	Total liabilities(b)		$	77
	(a)	The assets of Texas Solar 4 represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE.
	(b)	The liabilities of Texas Solar 4 represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary.
	Con Edison has a variable interest in Broken Bow II Wind Holdings, LLC (Broken Bow II), which is a non-consolidated entity in which Con Edison Development purchased a 50 percent membership interest in 2014. Broken Bow II owns a project company that developed a 75 MW (AC) wind electric production project in Nebraska. Electricity generated by the project is sold to Nebraska Public Power District pursuant to a long-term power purchase agreement.
	The following table summarizes the VIEs in which Con Edison Development has entered into as of December 31, 2014:
	Project Name(a)		Generating			Power Purchase			Year of Initial		Location		Maximum Exposure to
			Capacity			Agreement Term			Investment				Loss (In Millions)(c)
			Owned			in Years
	Pilesgrove			9			n/a	(b)		2010		New Jersey	$	26
	Mesquite Solar 1			83			20			2013		Arizona		111
	Copper Mountain Solar 2			75			25			2013		Nevada		80
	Copper Mountain Solar 3			128			20			2014		Nevada		175
	California Solar			55			25			2012		California		81
	Texas Solar 4			32			25			2014		Texas		58
	Broken Bow II			37			25			2014		Nebraska		57
	(a)	With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development.
	(b)	Pilesgrove has 3-5 year Solar Renewable Energy Credit (SREC) hedges in place.
	(c)	For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the balance sheet. For consolidated investments, maximum exposure is equal to the net assets of the investment on the balance sheet. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2014
Asset Retirement Obligations	Note R – 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 pipelines abandoned in place.
	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 its competitive 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 its competitive 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, 2014, the liabilities for asset retirement obligations of Con Edison and CECONY were $188 million and $185 million, respectively, as compared to $143 million for both Con Edison and CECONY at December 31, 2013. The increase in liabilities at December 31, 2014 was due to changes in estimated cash flows of $60 million and $57 million for Con Edison and CECONY, respectively, and accretion expense of $6 million for both Con Edison and CECONY. The increases were offset in part by liabilities settled of $21 million for both Con Edison and CECONY. Con Edison and CECONY also recorded reductions of $16 million and $17 million during the years ended December 31, 2014 and 2013, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.
CECONY [Member]
Asset Retirement Obligations	Note R – 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 pipelines abandoned in place.
	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 its competitive 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 its competitive 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, 2014, the liabilities for asset retirement obligations of Con Edison and CECONY were $188 million and $185 million, respectively, as compared to $143 million for both Con Edison and CECONY at December 31, 2013. The increase in liabilities at December 31, 2014 was due to changes in estimated cash flows of $60 million and $57 million for Con Edison and CECONY, respectively, and accretion expense of $6 million for both Con Edison and CECONY. The increases were offset in part by liabilities settled of $21 million for both Con Edison and CECONY. Con Edison and CECONY also recorded reductions of $16 million and $17 million during the years ended December 31, 2014 and 2013, 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, 2014
Related Party Transactions	Note S – Related Party Transactions
	The Utilities and Con Edison’s competitive businesses provide administrative and other services to each other pursuant to cost allocation procedures approved by the NYSPSC. 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, 2014, 2013 and 2012 were as follows:
		CECONY
	(Millions of Dollars)	2014		2013		2012
	Cost of services provided	$	90	$	84	$	83
	Cost of services received	$	57	$	52	$	49
	In addition, CECONY and O&R have joint gas supply arrangements, in connection with which CECONY sold to O&R $80 million, $72 million and $54 million of natural gas for the years ended December 31, 2014, 2013 and 2012, respectively. These amounts are net of the effect of related hedging transactions.
	FERC has authorized CECONY through 2015 to lend funds to O&R from time to time, for periods of not more than 12 months, in amounts not to exceed $250 million outstanding at any time, at prevailing market rates. There were no outstanding loans to O&R at December 31, 2014 and 2013.
CECONY [Member]
Related Party Transactions	Note S – Related Party Transactions
	The Utilities and Con Edison’s competitive businesses provide administrative and other services to each other pursuant to cost allocation procedures approved by the NYSPSC. 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, 2014, 2013 and 2012 were as follows:
		CECONY
	(Millions of Dollars)	2014		2013		2012
	Cost of services provided	$	90	$	84	$	83
	Cost of services received	$	57	$	52	$	49
	In addition, CECONY and O&R have joint gas supply arrangements, in connection with which CECONY sold to O&R $80 million, $72 million and $54 million of natural gas for the years ended December 31, 2014, 2013 and 2012, respectively. These amounts are net of the effect of related hedging transactions.
	FERC has authorized CECONY through 2015 to lend funds to O&R from time to time, for periods of not more than 12 months, in amounts not to exceed $250 million outstanding at any time, at prevailing market rates. There were no outstanding loans to O&R at December 31, 2014 and 2013.

New_Financial_Accounting_Stand

New Financial Accounting Standards	12 Months Ended
	Dec. 31, 2014
New Financial Accounting Standards	Note T – New Financial Accounting Standards
	In April 2014, the Financial Accounting Standards Board (FASB) issued amendments on reporting discontinued operations through Accounting Standards Update (ASU) No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” The amendments revise the definition of a discontinued operation as a disposal of a component of an entity or a group of components of an entity, or a business or nonprofit activity that represents a strategic shift that has or will have a major effect on an entity’s operations and financial results. The amendments also require additional disclosures for discontinued operations and individually significant disposals that do not qualify for discontinued operations presentation in the financial statements. For public entities, the amendments are effective prospectively for reporting periods beginning on or after December 15, 2014. The application of this guidance does not have a material impact on the Companies’ financial position, results of operations and liquidity.
	In May 2014, the FASB and the International Accounting Standards Board (IASB) jointly issued a revenue recognition standard that will supersede the revenue recognition
	requirements within Accounting Standards Codification (ASC) Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. The new guidance must be adopted using either a full retrospective approach or a modified retrospective approach. For public entities reporting under GAAP, the new guidance is effective for periods beginning after December 15, 2016. The Companies are in the process of evaluating the application and impact of the new guidance on the Companies’ financial position, results of operations and liquidity.
	In June 2014, the FASB issued ASU No. 2014-12, “Compensation—Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period (a consensus of the FASB Emerging Issues Task Force).” The amendments clarify the accounting treatment regarding performance targets. Under the new guidance, a performance target that affects vesting and that could be achieved after the requisite service period is required to be treated as a performance condition and should not be reflected in estimating the grant-date fair value of the award. Compensation cost should be recognized only when it becomes probable that the performance target will be achieved. The amendments are effective for periods beginning after December 15, 2015. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
	In August 2014, the FASB issued amendments on reporting about an entity’s ability to continue as a going concern in ASU No. 2014-15, “Presentation of Financial Statements – Going Concern (Subtopic 205 - 40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern.” The amendments provide guidance about management’s responsibility to evaluate whether there is substantial doubt surrounding an entity’s ability to continue as a going concern. If management concludes that substantial doubt exists, the amendments also require additional disclosures relating to management’s evaluation and conclusion. The amendments are effective for the annual reporting period ending after December 15, 2016 and interim periods thereafter. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
	In November 2014, the FASB issued amendments on pushdown accounting for subsidiaries and acquired entities in ASU No. 2014-17, “Business Combinations (Topic 805): Pushdown Accounting.” The amendments provide guidance as to whether and at what threshold an acquired entity can apply pushdown accounting in its separate financial statements. The amendments are effective as of the date of issuance. The application of this guidance does not have a material impact on the Companies’ financial position, results of operations and liquidity.
CECONY [Member]
New Financial Accounting Standards	Note T – New Financial Accounting Standards
	In April 2014, the Financial Accounting Standards Board (FASB) issued amendments on reporting discontinued operations through Accounting Standards Update (ASU) No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” The amendments revise the definition of a discontinued operation as a disposal of a component of an entity or a group of components of an entity, or a business or nonprofit activity that represents a strategic shift that has or will have a major effect on an entity’s operations and financial results. The amendments also require additional disclosures for discontinued operations and individually significant disposals that do not qualify for discontinued operations presentation in the financial statements. For public entities, the amendments are effective prospectively for reporting periods beginning on or after December 15, 2014. The application of this guidance does not have a material impact on the Companies’ financial position, results of operations and liquidity.
	In May 2014, the FASB and the International Accounting Standards Board (IASB) jointly issued a revenue recognition standard that will supersede the revenue recognition
	requirements within Accounting Standards Codification (ASC) Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. The new guidance must be adopted using either a full retrospective approach or a modified retrospective approach. For public entities reporting under GAAP, the new guidance is effective for periods beginning after December 15, 2016. The Companies are in the process of evaluating the application and impact of the new guidance on the Companies’ financial position, results of operations and liquidity.
	In June 2014, the FASB issued ASU No. 2014-12, “Compensation—Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period (a consensus of the FASB Emerging Issues Task Force).” The amendments clarify the accounting treatment regarding performance targets. Under the new guidance, a performance target that affects vesting and that could be achieved after the requisite service period is required to be treated as a performance condition and should not be reflected in estimating the grant-date fair value of the award. Compensation cost should be recognized only when it becomes probable that the performance target will be achieved. The amendments are effective for periods beginning after December 15, 2015. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
	In August 2014, the FASB issued amendments on reporting about an entity’s ability to continue as a going concern in ASU No. 2014-15, “Presentation of Financial Statements – Going Concern (Subtopic 205 - 40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern.” The amendments provide guidance about management’s responsibility to evaluate whether there is substantial doubt surrounding an entity’s ability to continue as a going concern. If management concludes that substantial doubt exists, the amendments also require additional disclosures relating to management’s evaluation and conclusion. The amendments are effective for the annual reporting period ending after December 15, 2016 and interim periods thereafter. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
	In November 2014, the FASB issued amendments on pushdown accounting for subsidiaries and acquired entities in ASU No. 2014-17, “Business Combinations (Topic 805): Pushdown Accounting.” The amendments provide guidance as to whether and at what threshold an acquired entity can apply pushdown accounting in its separate financial statements. The amendments are effective as of the date of issuance. The application of this guidance does not have a material impact on the Companies’ financial position, results of operations and liquidity.

Schedule_I_Condensed_Financial

Schedule I - Condensed Financial Information	12 Months Ended
	Dec. 31, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Schedule I - Condensed Financial Information	Schedule I
	Condensed Financial Information of Consolidated Edison, Inc.*
	Condensed Statement of Income and Comprehensive Income
	(Parent Company Only)
			For the Years Ended December 31,
	(Millions of Dollars, except per share amounts)		2014			2013			2012
	Equity in earnings of subsidiaries		$	1,101		$	1,062		$	1,154
	Other income (deductions), net of taxes			19			29			12
	Interest expense			(28	)		(29	)		(28	)
	Net Income for Common Stock		$	1,092		$	1,062		$	1,138
	Comprehensive Income for Common Stock		$	1,072		$	1,090		$	1,143
	Net Income Per Common Share – Basic		$	3.73		$	3.62		$	3.88
	Net Income Per Common Share – Diluted		$	3.71		$	3.61		$	3.86
	Dividends Declared Per Share Of Common Stock		$	2.52		$	2.46		$	2.42
	Average Number Of Shares Outstanding—Basic (In Millions)			292.9			292.9			292.9
	Average Number Of Shares Outstanding—Diluted (In Millions)			294			294.4			294.5
	*	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.*
	Condensed Statement of Cash Flows
	(Parent Company Only)
			For the Years Ended December 31,
	(Millions of Dollars)		2014			2013			2012
	Net Income		$	1,092		$	1,062		$	1,138
	Equity in earnings of subsidiaries			(1,101	)		(1,062	)		(1,154	)
	Dividends received from:
	CECONY			712			728			682
	O&R			40			38			34
	Competitive energy businesses			8			12			11
	Change in Assets:
	Special deposits			314			(264	)		–
	Income taxes receivable			(224	)		–			–
	Other – net			(199	)		166			(208	)
	Net Cash Flows from Operating Activities			642			680			503
	Investing Activities
	Contributions to subsidiaries			(1	)		–			(100	)
	Net Cash Flows Used in Investing Activities			(1	)		–			(100	)
	Financing Activities
	Net proceeds of short-term debt			101			58			115
	Retirement of long-term debt			(2	)		(1	)		(1	)
	Issuance of common shares for stock plans, net of repurchases			(10	)		(8	)		(9	)
	Common stock dividends			(739	)		(721	)		(709	)
	Net Cash Flows Used in Financing Activities			(650	)		(672	)		(604	)
	Net Change for the Period			(9	)		8			(201	)
	Balance at Beginning of Period			12			4			205
	Balance at End of Period		$	3		$	12		$	4
	*	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.*
	Condensed Balance Sheet
	(Parent Company Only)
			At December 31,
	(Millions of Dollars)		2014			2013
	Assets
	Current Assets
	Cash and temporary cash investments		$	3		$	12
	Special deposits			1			315
	Accounts receivable – other			–			185
	Income taxes receivable			224			–
	Accounts receivable from affiliated companies			381			950
	Prepayments			5			2
	Other current assets			4			–
	Total Current Assets			618			1,464
	Investments in subsidiaries			12,277			11,954
	Goodwill			406			406
	Deferred income tax			18			14
Other noncurrent assets			11			4
Total Assets		$	13,330		$	13,842
Liabilities and Shareholders’ Equity
Current Liabilities
Long-term debt due within one year		$	2		$	2
Notes payable			274			173
Accounts payable to affiliated companies			147			148
Accrued taxes			13			426
Other current liabilities			10			538
Total Current Liabilities			446			1,287
Total Liabilities			446			1,287
Long-term debt			308			310
Shareholders’ Equity
Common stock, including additional paid-in capital			5,023			5,027
Retained earnings			7,553			7,218
Total Shareholders’ Equity			12,576			12,245
Total Liabilities and Shareholders’ Equity		$	13,330		$	13,842
*	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_Qual

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2014
Schedule II - Valuation and Qualifying Accounts	Schedule II
	Valuation and Qualifying Accounts
	For the Years Ended December 31, 2014, 2013 and 2012
							COLUMN C
							Additions
	Company (Millions of Dollars)		COLUMN A		COLUMN B		-1		-2		COLUMN D		COLUMN E
			Description		Balance at		Charged To		Charged		Deductions(b)		Balance
					Beginning		Costs And		To Other				At End of
					of Period		Expenses		Accounts				Period
	Con Edison		Allowance for uncollectible
			accounts(a):
				2014	$	103	$	98	$	-	$	95	$	106
				2013	$	105	$	86		-	$	88	$	103
				2012	$	97	$	96		-	$	88	$	105
	CECONY		Allowance for uncollectible
			accounts(a):
				2014	$	95	$	91	$	-	$	88	$	98
				2013	$	96	$	82		-	$	83	$	95
				2012	$	88	$	90		-	$	82	$	96
	(a)	This is a valuation account deducted in the balance sheet from the assets (Accounts receivable-customers) to which they apply.
	(b)	Accounts written off less cash collections, miscellaneous adjustments and amounts reinstated as receivables previously written off.
CECONY [Member]
Schedule II - Valuation and Qualifying Accounts	Schedule II
	Valuation and Qualifying Accounts
	For the Years Ended December 31, 2014, 2013 and 2012
							COLUMN C
							Additions
	Company (Millions of Dollars)		COLUMN A		COLUMN B		-1		-2		COLUMN D		COLUMN E
			Description		Balance at		Charged To		Charged		Deductions(b)		Balance
					Beginning		Costs And		To Other				At End of
					of Period		Expenses		Accounts				Period
	Con Edison		Allowance for uncollectible
			accounts(a):
				2014	$	103	$	98	$	-	$	95	$	106
				2013	$	105	$	86		-	$	88	$	103
				2012	$	97	$	96		-	$	88	$	105
	CECONY		Allowance for uncollectible
			accounts(a):
				2014	$	95	$	91	$	-	$	88	$	98
				2013	$	96	$	82		-	$	83	$	95
				2012	$	88	$	90		-	$	82	$	96
	(a)	This is a valuation account deducted in the balance sheet from the assets (Accounts receivable-customers) to which they apply.
	(b)	Accounts written off less cash collections, miscellaneous adjustments and amounts reinstated as receivables previously written off.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
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 Q), as required. All intercompany balances and 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. The Utilities are receiving or being credited with a return on all of their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on all of their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable state regulators.
	Other significant accounting policies of the Companies are referenced below in this Note A and in the notes that follow.
Plant and Depreciation	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 R.
	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 1.6 percent, 4.0 percent and 6.5 percent for 2014, 2013 and 2012, respectively. The AFUDC rates for O&R were 2.6 percent, 5.7 percent and 7.0 percent for 2014, 2013 and 2012, 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 3.1 percent, 3.2 percent and 3.1 percent for 2014, 2013 and 2012, respectively. The average depreciation rates for O&R were 2.9 percent, 2.8 percent and 2.9 percent for 2014, 2013 and 2012, respectively.
	The estimated lives for utility plant for CECONY range from 5 to 85 years for electric and 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, 2014 and 2013, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:
			Con Edison						CECONY
	(Millions of Dollars)		2014			2013			2014		2013
	Electric
	Generation		$	451		$	452		$	451	$	452
	Transmission			2,956			2,776			2,744		2,597
	Distribution			16,361			15,277			15,531		14,496
	Gas*			5,006			4,469			4,530		4,013
	Steam			1,795			1,790			1,795		1,790
	General			1,650			1,565			1,498		1,433
	Held for future use			76			73			65		62
	Construction work in progress			1,031			1,393			971		1,303
	Net Utility Plant		$	29,326		$	27,795		$	27,585	$	26,146
	*	Primarily distribution.
	Under the Utilities’ rate plans, the aggregate annual depreciation allowance in effect at December 31, 2014 was $1,048 million, including $993 million under CECONY’s electric, gas and steam rate plans that have been approved by the New York State Public Service Commission (NYSPSC).
	Non-Utility Plant
	Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the competitive energy businesses’ renewable electric production and gas storage. 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 range from 3 to 30 years.
Goodwill	Goodwill
	Con Edison tests goodwill for impairment at least annually. Goodwill is tested for impairment using a two-step approach. The first step of the 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, the second step is performed to measure the amount of impairment loss, if any. The second step requires a calculation of the implied fair value of goodwill. See Note K.
Impairments	Impairments
	Con Edison evaluates the impairment of long-lived assets, based on projections of undiscounted future cash flows, whenever events or changes in circumstances indicate that the carrying amounts of such assets may not be recoverable. In the event an evaluation indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are written down to their estimated fair value. No impairment charges were recognized in 2014, 2013 or 2012.
Revenues	Revenues
	The Utilities and Con Edison Solutions recognize revenues for energy service on a monthly billing cycle basis. 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 Utilities and Con Edison Solutions accrue revenues at the end of each month for estimated energy service not yet billed to customers.
	CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism 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)		2014			2013			2012
	Con Edison		$	365		$	354		$	334
	CECONY			343			329			306
Public Utility Information	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 or two months). For the Utilities’ gas costs, differences between actual and billed gas costs during the 12-month period ending each August are charged or refunded to customers during a subsequent 12-month period.
	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
	Investments consist primarily of the investments of Con Edison’s competitive energy businesses, which are accounted for under the equity method (depending on the subsidiaries’ percentage ownership). Utilities’ investments are recorded at fair value and include the investments of the deferred income plan and the supplemental retirement income plan in trust-owned life insurance assets.
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 (OCI), net of tax. Such amounts will be adjusted as they are subsequently recognized as components of net 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 net 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. Generally, O&R also defers such difference pursuant to its rate plans. See Note B – Regulatory Matters.
	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.
Income Taxes	Federal Income Tax
	In accordance with the accounting rules for income taxes, the Companies have recorded an accumulated deferred federal income tax liability for temporary differences between the book and tax basis of assets and liabilities at current tax rates. 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 tax liability, in accordance with the accounting rules for regulated operations, the Utilities have established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense. See Notes B and L. In 1993, the NYSPSC issued a Policy Statement approving accounting procedures consistent with the accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. See 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 tax sharing agreements among the members of the consolidated group. Tax loss carryforwards are allocated among members in accordance with consolidated tax return regulations.
	State Income Tax
	Con Edison and its subsidiaries file a combined New York State Corporation Business Franchise Tax Return. Similar to a federal consolidated income tax return, the income of all entities in the combined group is subject to New York State taxation, after adjustments for differences between federal and New York law and apportionment of income among the states in which the company does business. Each member’s share of the New York State tax is based on its own New York State taxable income or loss.
Research and Development Costs	Research and Development Costs
	Generally research and development costs are charged to operating expenses as incurred. Research and development costs were as follows:
			For the Years Ended December 31,
	(Millions of Dollars)		2014			2013			2012
	Con Edison		$	22		$	18		$	21
	CECONY			20			16			19
Reclassification	Reclassification
	Certain prior year amounts have been reclassified to conform with the current year presentation.
Earnings Per Common Share	Earnings Per Common Share
	Con Edison presents basic and diluted earnings per share on the face of its consolidated income statement. Basic earnings per share (EPS) are calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.
	Potentially dilutive securities for Con Edison consist of restricted stock units, deferred stock units and stock options for which the average market price of the common shares for the period was greater than the exercise price. See Note M.
	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)		2014			2013			2012
	Net income for common stock		$	1,092		$	1,062		$	1,138
	Weighted average common shares outstanding – Basic			292.9			292.9			292.9
	Add: Incremental shares attributable to effect of potentially dilutive securities			1.1			1.5			1.6
	Adjusted weighted average common shares outstanding – Diluted			294			294.4			294.5
	Net Income for common stock per common share – basic		$	3.73		$	3.62		$	3.88
	Net Income for common stock per common share – diluted		$	3.71		$	3.61		$	3.86
	The computation of diluted EPS for the years ended December 31, 2014, 2013 and 2012 exclude immaterial amounts of performance share awards that were not included because of their anti-dilutive effect.
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.
Changes in Accumulated Other Comprehensive Income by Component	Changes in Accumulated Other Comprehensive Income by Component
	Changes to accumulated other comprehensive income (OCI) for Con Edison and CECONY are as follows:
	(Millions of Dollars)		Con Edison			CECONY
	Accumulated OCI, net of taxes, at December 31, 2012		$	(53	)	$	(9	)
	OCI before reclassifications, net of tax of $(15) and $(1) for Con Edison and CECONY, respectively			21			2
	Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(5) and $(1) for Con Edison and CECONY, respectively(a)(b)			7			1
	Total OCI, net of taxes, at December 31, 2013			28			3
	Accumulated OCI, net of taxes, at December 31, 2013(b)		$	(25	)	$	(6	)
	OCI before reclassifications, net of tax of $18 and $4 for Con Edison and CECONY, respectively			(26	)		(6	)
	Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(4) and $(1) for Con Edison and CECONY, respectively(a)(b)			6			1
	Total OCI, net of taxes, at December 31, 2014			(20	)		(5	)
	Accumulated OCI, net of taxes, at December 31, 2014(b)		$	(45	)	($	11	)
	(a)	For the portion of unrecognized pension and other postretirement benefit costs relating to the regulated Utilities, costs are recorded into, and amortized out of, regulatory assets instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of net periodic pension and other postretirement benefit cost. See Notes E and F.
	(b)	Tax reclassified from accumulated OCI is reported in the income tax expense line item of the income statement.
New Financial Accounting Standards	New Financial Accounting Standards
	In April 2014, the Financial Accounting Standards Board (FASB) issued amendments on reporting discontinued operations through Accounting Standards Update (ASU) No. 2014-08, “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” The amendments revise the definition of a discontinued operation as a disposal of a component of an entity or a group of components of an entity, or a business or nonprofit activity that represents a strategic shift that has or will have a major effect on an entity’s operations and financial results. The amendments also require additional disclosures for discontinued operations and individually significant disposals that do not qualify for discontinued operations presentation in the financial statements. For public entities, the amendments are effective prospectively for reporting periods beginning on or after December 15, 2014. The application of this guidance does not have a material impact on the Companies’ financial position, results of operations and liquidity.
	In May 2014, the FASB and the International Accounting Standards Board (IASB) jointly issued a revenue recognition standard that will supersede the revenue recognition
	requirements within Accounting Standards Codification (ASC) Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. The new guidance must be adopted using either a full retrospective approach or a modified retrospective approach. For public entities reporting under GAAP, the new guidance is effective for periods beginning after December 15, 2016. The Companies are in the process of evaluating the application and impact of the new guidance on the Companies’ financial position, results of operations and liquidity.
	In June 2014, the FASB issued ASU No. 2014-12, “Compensation—Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period (a consensus of the FASB Emerging Issues Task Force).” The amendments clarify the accounting treatment regarding performance targets. Under the new guidance, a performance target that affects vesting and that could be achieved after the requisite service period is required to be treated as a performance condition and should not be reflected in estimating the grant-date fair value of the award. Compensation cost should be recognized only when it becomes probable that the performance target will be achieved. The amendments are effective for periods beginning after December 15, 2015. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
	In August 2014, the FASB issued amendments on reporting about an entity’s ability to continue as a going concern in ASU No. 2014-15, “Presentation of Financial Statements – Going Concern (Subtopic 205 - 40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern.” The amendments provide guidance about management’s responsibility to evaluate whether there is substantial doubt surrounding an entity’s ability to continue as a going concern. If management concludes that substantial doubt exists, the amendments also require additional disclosures relating to management’s evaluation and conclusion. The amendments are effective for the annual reporting period ending after December 15, 2016 and interim periods thereafter. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
	In November 2014, the FASB issued amendments on pushdown accounting for subsidiaries and acquired entities in ASU No. 2014-17, “Business Combinations (Topic 805): Pushdown Accounting.” The amendments provide guidance as to whether and at what threshold an acquired entity can apply pushdown accounting in its separate financial statements. The amendments are effective as of the date of issuance. The application of this guidance does not have a material impact on the Companies’ financial position, results of operations and liquidity.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Capitalized Cost of Utility Plant	At December 31, 2014 and 2013, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:
			Con Edison						CECONY
	(Millions of Dollars)		2014			2013			2014		2013
	Electric
	Generation		$	451		$	452		$	451	$	452
	Transmission			2,956			2,776			2,744		2,597
	Distribution			16,361			15,277			15,531		14,496
	Gas*			5,006			4,469			4,530		4,013
	Steam			1,795			1,790			1,795		1,790
	General			1,650			1,565			1,498		1,433
	Held for future use			76			73			65		62
	Construction work in progress			1,031			1,393			971		1,303
	Net Utility Plant		$	29,326		$	27,795		$	27,585	$	26,146
	*	Primarily distribution.
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)		2014			2013			2012
	Con Edison		$	365		$	354		$	334
	CECONY			343			329			306
Research and Development Costs	Generally research and development costs are charged to operating expenses as incurred. Research and development costs were as follows:
			For the Years Ended December 31,
	(Millions of Dollars)		2014			2013			2012
	Con Edison		$	22		$	18		$	21
	CECONY			20			16			19
Earnings Per Common Share	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)		2014			2013			2012
	Net income for common stock		$	1,092		$	1,062		$	1,138
	Weighted average common shares outstanding – Basic			292.9			292.9			292.9
	Add: Incremental shares attributable to effect of potentially dilutive securities			1.1			1.5			1.6
	Adjusted weighted average common shares outstanding – Diluted			294			294.4			294.5
	Net Income for common stock per common share – basic		$	3.73		$	3.62		$	3.88
	Net Income for common stock per common share – diluted		$	3.71		$	3.61		$	3.86
Changes in Accumulated Other Comprehensive Income by Component	Changes to accumulated other comprehensive income (OCI) for Con Edison and CECONY are as follows:
	(Millions of Dollars)		Con Edison			CECONY
	Accumulated OCI, net of taxes, at December 31, 2012		$	(53	)	$	(9	)
	OCI before reclassifications, net of tax of $(15) and $(1) for Con Edison and CECONY, respectively			21			2
	Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(5) and $(1) for Con Edison and CECONY, respectively(a)(b)			7			1
	Total OCI, net of taxes, at December 31, 2013			28			3
	Accumulated OCI, net of taxes, at December 31, 2013(b)		$	(25	)	$	(6	)
	OCI before reclassifications, net of tax of $18 and $4 for Con Edison and CECONY, respectively			(26	)		(6	)
	Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(4) and $(1) for Con Edison and CECONY, respectively(a)(b)			6			1
	Total OCI, net of taxes, at December 31, 2014			(20	)		(5	)
	Accumulated OCI, net of taxes, at December 31, 2014(b)		$	(45	)	($	11	)
	(a)	For the portion of unrecognized pension and other postretirement benefit costs relating to the regulated Utilities, costs are recorded into, and amortized out of, regulatory assets instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of net periodic pension and other postretirement benefit cost. See Notes E and F.
	(b)	Tax reclassified from accumulated OCI is reported in the income tax expense line item of the income statement.

Regulatory_Matters_Tables

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2014
Regulatory Assets and Liabilities	Regulatory Assets and Liabilities
	Regulatory assets and liabilities at December 31, 2014 and 2013 were comprised of the following items:
			Con Edison					CECONY
	(Millions of Dollars)		2014			2013		2014		2013
	Regulatory assets
	Unrecognized pension and other postretirement costs		$	4,846		$	2,730	$	4,609	$	2,610
	Future income tax			2,273			2,145		2,166		2,030
	Environmental remediation costs			925			938		820		830
	Deferred storm costs			319			441		224		334
	Revenue taxes			219			207		208		196
	Surcharge for New York State assessment			99			78		92		74
	Pension and other postretirement benefits deferrals			66			237		42		211
	Net electric deferrals			63			83		63		83
	Unamortized loss on reacquired debt			57			65		55		62
	O&R property tax reconciliation			36			22		-		-
	O&R transition bond charges			27			33		-		-
	Preferred stock redemption			27			28		27		28
	Deferred derivative losses – noncurrent			25			8		23		7
	Recoverable energy costs – noncurrent			19			29		17		28
	Workers’ compensation			8			12		8		12
	Other			147			145		127		134
	Regulatory assets – noncurrent			9,156			7,201		8,481		6,639
	Deferred derivative losses – current			97			25		92		22
	Recoverable energy costs – current			41			4		40		4
	Future income tax – current			10			-		-		-
	Regulatory assets – current			148			29		132		26
	Total Regulatory Assets		$	9,304		$	7,230	$	8,613	$	6,665
	Regulatory liabilities
	Allowance for cost of removal less salvage		$	598		$	540	$	499	$	453
	Property tax reconciliation			295			322		295		322
	2014 rate plan rate base revenue deferrals			155			-		155		-
	Net unbilled revenue deferrals			138			133		138		133
	Prudence proceeding			105			40		105		40
	Property tax refunds			87			130		87		130
	Long-term interest rate reconciliation			78			105		78		105
	New York State income tax rate change			62			-		59		-
	Carrying charges on repair allowance and bonus depreciation			58			88		57		87
	Pension and other postretirement benefit deferrals			46			50		37		50
	World Trade Center settlement proceeds			41			62		41		62
	Carrying charges on T&D net plant – electric and steam			21			28		20		20
	Electric excess earnings			19			22		18		18
	Other			290			208		248		178
	Regulatory liabilities – noncurrent			1,993			1,728		1,837		1,598
	Refundable energy costs – current			128			100		84		66
	Revenue decoupling mechanism			30			34		30		30
	Future income tax			24			-		24		-
	Deferred derivative gains – current			5			14		4		11
	Regulatory liabilities—current			187			148		142		107
	Total Regulatory Liabilities		$	2,180		$	1,876	$	1,979	$	1,705
Rockland Electric Company (RECO) [Member]
Summary of Utilities Rate Plans	Rockland Electric Company (RECO)
	Effective period		May 2010 – July 2014		August 2014 – July 2015
	Base rate changes		Yr. 1 – $9.8 million		Yr. 1 – $13.0 million
	Amortization to income of net		$(3.9) million over four years and $(4.9) million of deferred storm costs over five years		$0.4 million over three years and $(25.6) million of deferred storm costs over four years
	regulatory (assets) and liabilities
	Recoverable energy costs		Current rate recovery of purchased power costs.		Continuation of current rate recovery of purchased power costs.
	Cost reconciliations		None		None
	Average rate base		$148.6 million		$172.2 million
	Weighted average cost of capital		8.21 percent		7.83 percent
	(after-tax)
	Authorized return on common equity		10.3 percent		9.75 percent
	Cost of long-term debt		6.16 percent		5.89 percent
	Common equity ratio		50 percent		50 percent
Electric Transmission [Member] | CECONY [Member]
Summary of Utilities Rate Plans	The following tables contain a summary of the Utilities’ rate plans:
	CECONY – Electric
	Effective period		April 2010 – December 2013		January 2014 – December 2015
	Base rate changes(a)		Yr. 1 – $420 million		Yr. 1 – $(76.2) million(c)
			Yr. 2 – $420 million		Yr. 2 – $124.0 million(c)
			Yr. 3 – $287 million(b)
	Amortizations to income of net		$(75.3) million over three years		$(37) million over two years, that includes $107 million annually for deferred major storm costs
	regulatory (assets) and liabilities
	Other revenue sources		Retention of $120 million of annual transmission congestion revenues from the sale of transmission rights ($90 million for the period April 1, 2013 to December 31, 2013).		Retention of $90 million of annual transmission congestion revenues.
	Revenue decoupling mechanisms		In 2012 and 2013, the company deferred for customer benefit $59 million and $34 million of revenues, respectively.		In 2014, the company deferred for customer benefit $146 million of revenues.
	Recoverable energy costs		Current rate recovery of purchased power and fuel costs.		Continuation of current rate recovery of purchased power and fuel costs(d).
	Negative revenue adjustments		Potential penalties (up to $350 million annually) if certain performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.		Potential penalties (up to $400 million annually) if certain performance targets are not met. In 2014, the company recorded a $5 million negative revenue adjustment.
	Cost reconciliations(e)		In 2012 and 2013, the company deferred $146 million of net regulatory liabilities and $35 million of net regulatory assets, respectively.		In 2014, the company deferred $57 million of net regulatory liabilities.
	Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
			Transmission and distribution: Yr. 1 –$13,818 million; Yr. 2 – $14,742 million;		Transmission and distribution: Yr. 1 – $16,869 million; Yr. 2 – $17,401 million
			Yr. 3 – $15,414 million		Storm hardening: Yr. 1 – $89 million; Yr. 2 – $177 million
			Enterprise resource project: Yr. 2 – $25 million;		Other: Yr. 1 – $2,034 million; Yr. 2 – $2,102 million
			Yr. 3 -$115 million		The company deferred an immaterial amount as a regulatory liability in 2014.
			Other: Yr. 1 – $1,487 million;
			Yr. 2 – $1,565 million; Yr. 3 – $1,650 million
			The company deferred an immaterial amount and $7 million as a regulatory liability in 2012 and 2013, respectively.
	Average rate base		Yr. 1 – $14,887 million		Yr. 1 – $17,323 million
			Yr. 2 – $15,987 million		Yr. 2 – $18,113 million
			Yr. 3 – $16,826 million
	Weighted average cost of capital (after-tax)		7.76 percent		Yr. 1 – 7.05 percent
					Yr. 2 – 7.08 percent
	Authorized return on common equity		10.15 percent assuming the company achieved austerity measures of $27 million, $20 million and $13 million for Yrs. 1, 2 and 3. Austerity measures were achieved.		9.2 percent
	Earnings sharing		Actual earnings above an annual earnings threshold of 11.15 percent for Yr. 1 and 10.65 percent for Yrs. 2 and 3 were to be applied to reduce regulatory assets for pensions and other postretirement benefits and other costs.		Most earnings above an annual earnings threshold of 9.8 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 $17.5 million above the threshold for the period ended 2013.
	Cost of long-term debt		5.65 percent		Yr. 1 – 5.17 percent
					Yr. 2 – 5.23 percent
	Common equity ratio		48 percent		48 percent
	(a)	$249 million of annual revenues collected from electric customers is subject to potential refund following NYSPSC staff review of costs. See “Other Regulatory Matters” below in this Note B. Revenues for each of 2014 and 2015 include $21 million as funding for major storm reserve.
	(b)	Temporary portion of the increase ($134 million) that was scheduled to go into effect April 1, 2012 was eliminated by the application of available credits.
	(c)	The impact of these base rate changes is being deferred which will result in a $30 million regulatory liability at December 31, 2015.
	(d)	With respect to transmission service provided pursuant to the open access transmission tariff of PJM Interconnection L.L.C. (PJM), the company recovered in 2014 part of charges incurred during 2013 (approximately $20 million) and, commencing in January 2014 and unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. In January 2014, PJM submitted to FERC a request that would substantially increase the charges for the transmission service. CECONY has opposed this increase.
	(e)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.
Electric Transmission [Member] | O&R [Member]
Summary of Utilities Rate Plans	O&R New York – Electric
	Effective period		July 2012 – June 2015
	Base rate changes		Yr. 1 – $19.4 million
			Yr. 2 – $8.8 million
			Yr. 3 – $15.2 million
	Amortizations to income of net		$(32.2) million over three years
	regulatory (assets) and liabilities
	Revenue decoupling mechanisms		In 2012, 2013 and 2014, the company deferred for the customer’s benefit $2.6 million, $3.2 million and ($3.4) million.
	Recoverable energy costs		Current rate recovery of purchased power and fuel costs.
	Negative revenue adjustments		Potential penalties (up to $3 million annually) if certain customer service and system reliability performance targets are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.
	Cost reconciliations		In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase to regulatory assets, respectively.
	Net utility plant reconciliations		Target levels reflected in rates were:
			Yr. 1 – $678 million; Yr. 2- $704 million; Yr. 3 – $753 million
			The company increased its regulatory liability by $4.2 million in 2012. The company reduced its regulatory, liability by $1.1 million and $2.3 million in 2013 and 2014, respectively.
	Average rate base		Yr. 1 – $671 million
			Yr. 2 – $708 million
			Yr. 3 – $759 million
	Weighted average cost of capital (after-tax)		Yr. 1 – 7.61 percent
			Yr. 2 – 7.65 percent
			Yr. 3 – 7.48 percent
	Authorized return on common equity		Yr. 1 – 9.4 percent
			Yr. 2 – 9.5 percent
			Yr. 3 – 9.6 percent
	Earnings sharing		The company recorded a regulatory liability of $1 million for earnings above the sharing threshold under the rate plan as of December 31, 2014.
	Cost of long-term debt		Yr. 1 – 6.07 percent
			Yr. 2 – 6.07 percent
			Yr. 3 – 5.64 percent
	Common equity ratio		48 percent
Electric Transmission [Member] | Pike County Light & Power Company (Pike) [Member]
Summary of Utilities Rate Plans	Pike County Light & Power Company (Pike) – Electric
	Effective period		April 2009 – August 2014		September 2014 – August 2015
	Base rate changes(a)		Yr. 1 – $0.9 million		Yr. 1 – $1.25 million
	Amortization to income of net regulatory (assets) and liabilities		$0.1 million over 5 years		$(0.7) million of deferred storm costs over five years
	Cost reconciliations		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as regulatory liabilities in 2012 and 2013.		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as a regulatory liability in 2014.
	(a)	Under the current plan, the earliest that the company can file for a new base rate change is September 1, 2016.
Gas [Member] | CECONY [Member]
Summary of Utilities Rate Plans	CECONY – Gas
	Effective period		October 2010 – December 2013		January 2014 – December 2016
	Base rate changes(a)		Yr. 1 – $47 million		Yr. 1 – $(54.6) million(b)
			Yr. 2 – $48 million		Yr. 2 – $38.6 million(b)
			Yr. 3 – $47 million		Yr. 3 – $56.8 million(b)
	Amortizations to income of net		$(53.1) million over three years		$4 million over three years
	regulatory (assets) and liabilities
	Other revenue sources		Retention of revenues from non-firm customers of up to $58 million and 25 percent of any such revenues above $58 million. The company retained $57 million and $64 million of such revenues in 2012 and 2013, respectively.		Retention of revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. The company retained $70 million of such revenues in 2014.
	Revenue decoupling mechanisms		In 2012 and 2013, the company deferred $22 million and $36 million of regulatory liabilities, respectively.		In 2014, the company deferred $28 million of regulatory liabilities.
	Recoverable energy costs		Current rate recovery of purchased gas costs.		Continuation of current rate recovery of purchased gas costs.
	Negative revenue adjustments		Potential penalties (up to $12.6 million annually)		Potential penalties (up to $33 million in 2014, $44 million in 2015, and $56 million in 2016) if certain gas performance targets are not met. In 2014, the company did not record any negative revenue adjustments.
			if certain gas customer service and system performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.
	Cost reconciliations(c)		In 2012 and 2013, the company deferred $9 million and $26 million of net regulatory assets, respectively.		In 2014, the company deferred $38 million of net regulatory liabilities.
	Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
			Gas delivery Yr. 1 – $2,934 million;		Gas delivery Yr. 1 – $3,899 million;
			Yr. 2 – $3,148 million; Yr. 3 – $3,346 million		Yr. 2 – $4,258 million; Yr. 3 – $4,698 million
			For 2012 and 2013, $2.9 million and $9.5 million were deferred as a regulatory liability respectively.		Storm hardening: Yr. 1 – $3 million;
					Yr. 2 – $8 million; Yr. 3 – $30 million
					There were no deferrals recorded in 2014.
	Average rate base		Yr. 1 – $3,027 million		Yr. 1 – $3,521 million
			Yr. 2 – $3,245 million		Yr. 2 – $3,863 million
			Yr. 3 – $3,434 million		Yr. 3 – $4,236 million
	Weighted average cost of capital		7.46 percent		Yr. 1 – 7.10 percent
	(after-tax)				Yr. 2 – 7.13 percent
					Yr. 3 – 7.21 percent
	Authorized return on common equity		9.6 percent assuming the company achieved unspecified austerity measures of $4 million and $2 million in 2012 and 2013. Austerity measures were achieved.		9.3 percent
	Earnings sharing		Actual earnings did not exceed the thresholds of 10.35 percent in Yr. 1 and 10.15 percent in Yrs. 2 and 3.		Most 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.
	Cost of long-term debt		5.57 percent		Yr. 1 – 5.17 percent
					Yr. 2 – 5.23 percent
					Yr. 3 – 5.39 percent
	Common equity ratio		48 percent		48 percent
	(a)	$32 million of annual revenues collected from gas customers is subject to potential refund. See “Other Regulatory Matters” below.
	(b)	The impact of these base rate changes is being deferred which will result in a $32 million regulatory liability at December 31, 2016.
	(c)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.
Gas [Member] | O&R [Member]
Summary of Utilities Rate Plans	O&R New York – Gas
	Effective period		November 2009 – December 2014
	Base rate changes		Yr. 1 – $9 million
			Yr. 2 – $9 million
			Yr. 3 – $4.6 million
			Yr. 3 – $4.3 million collected through a surcharge
	Amortization to income of net regulatory (assets) and liabilities		$(2) million over three years
	Revenue decoupling mechanisms		In 2012, 2013 and 2014, the company deferred $4.7 million, $0.7 million and $(0.1) million of regulatory liabilities, respectively.
	Recoverable energy costs		Current rate recovery of purchased gas costs.
	Negative revenue adjustments		Potential penalties (up to $1.4 million annually) if certain operations and customer service requirements are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.
	Cost reconciliations		In 2012, 2013 and 2014, the company deferred $0.7 million, $8.3 million and $8.3 million as net regulatory assets, respectively.
	Net utility plant reconciliations		The company deferred $0.7 million in 2012 as a regulatory asset and no deferrals were recorded for 2013 or 2014.
	Average rate base		Yr. 1 – $280 million
			Yr. 2 – $296 million
			Yr. 3 – $309 million
	Weighted average cost of capital (after-tax)		8.49 percent
	Authorized return on common equity		10.4 percent
	Earnings sharing		Earnings above an annual earnings threshold of 11.4 percent are to be applied to reduce regulatory assets. In 2012, 2013 and 2014, earnings did not exceed the earnings threshold.
	Cost of long-term debt		6.81 percent
	Common equity ratio		48 percent
Gas [Member] | Pike County Light & Power Company (Pike) [Member]
Summary of Utilities Rate Plans	Pike – Gas
	Effective period		April 2009 – August 2014		September 2014 – August 2015
	Base Rate changes(a)		Yr. 1 – $0.3 million		Yr. 1 – $0.1 million
	Amortization to income of net regulatory (assets) and liabilities		None		None
	Cost reconciliations		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as regulatory liabilities in 2012 and 2013.		True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as a regulatory liability in 2014.
	(a)	Under the current plan, the earliest that the company can file for a new base rate change is September 1, 2016.
Steam [Member] | CECONY [Member]
Summary of Utilities Rate Plans	CECONY – Steam
	Effective period		October 2010 – December 2013		January 2014 – December 2016
	Base rate changes(a)		Yr. 1 – $49.5 million		Yr. 1 – $(22.4) million(b)
			Yr. 2 – $49.5 million		Yr. 2 – $19.8 million(b)
			Yr. 3 – $17.8 million		Yr. 3 – $20.3 million(b)
			Yr. 3 – $31.7 million collected through a surcharge
	Amortizations to income of net		$(20.1) million over three years		$37 million over three years
	regulatory (assets) and liabilities
	Recoverable energy costs		Current rate recovery of purchased power and fuel costs.		Continuation of current rate recovery of purchased power and fuel costs.
	Negative revenue adjustments		Potential penalties (up to $1 million annually) if certain steam performance targets are not met. In 2012 and 2013, the company did not record any negative revenue adjustments.		Potential penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014, the company did not record any negative revenue adjustments.
	Cost reconciliations(c)		In 2012 and 2013, the company deferred $12 million and $17 million of net regulatory liabilities, respectively.		In 2014, the company deferred $42 million of net regulatory liabilities.
	Net utility plant reconciliations		Target levels reflected in rates were:		Target levels reflected in rates were:
			Production Yr. 1 – $415 million;		Production Yr. 1 – $1,752 million;
			Yr. 2 – $426 million; Yr. 3 – $433 million		Yr. 2 – $1,732 million; Yr. 3 – $1,720 million
			Distribution: Yr. 1 – $521 million; Yr. 2 – $534 million; Yr. 3 – $543 million		Distribution: Yr. 1 – $6 million; Yr. 2 – $11 million; Yr. 3 – $25 million
			The company reduced its regulatory liability by $0.2 million in 2012 and made no deferral in 2013.		The company reduced its regulatory liability by $1.1 million in 2014.
	Average rate base		Yr. 1 – $1,589 million		Yr. 1 – $1,511 million
			Yr. 2 – $1,603 million		Yr. 2 – $1,547 million
			Yr. 3 – $1,613 million		Yr. 3 – $1,604 million
	Weighted average cost of		7.46 percent		Yr. 1 – 7.10 percent
	capital (after-tax)				Yr. 2 – 7.13 percent
					Yr. 3 – 7.21 percent
	Authorized return on common equity		9.6 percent (assuming company achieved unspecified austerity measures of $3 million and $2 million in 2012 and 2013). Austerity measures were achieved.		9.3 percent
	Earnings sharing		Weather normalized earnings did not exceed the threshold of 10.35 percent in Yr. 1 and 10.15 percent in Yrs. 2 and 3. In 2013, actual earnings were $0.5 million above the earnings threshold of 10.15 percent.		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.
	Cost of long-term debt		5.57 percent		Yr. 1 – 5.17 percent
					Yr. 2 – 5.23 percent
					Yr. 3 – 5.39 percent
	Common equity ratio		48 percent		48 percent
	(a)	$6 million of annual revenues collected from steam customers is subject to potential refund. See “Other Regulatory Matters” below in this Note B.
	(b)	The impact of these base rate changes is being deferred which will result in an $8 million regulatory liability at December 31, 2016.
	(c)	Deferrals for property taxes were limited to 80 percent (90 percent beginning 2014) 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.

Capitalization_Tables

Capitalization (Tables)	12 Months Ended
	Dec. 31, 2014
Text Block [Abstract]
Schedule of Long-Term Debt Maturities	Long-term Debt
	Long-term debt maturing in the period 2015-2019 is as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	560	$	350
	2016		731		650
	2017		6		-
	2018		1,260		1,200
	2019		540		475
Carrying Amounts and Fair Values of Long-Term Debt	The carrying amounts and fair values of long-term debt at December 31, 2014 and 2013 are:
	(Millions of Dollars)	2014				2013
	Long-Term Debt	Carrying		Fair		Carrying		Fair
	(including current	Amount		Value		Amount		Value
	portion)
	Con Edison	$	12,191	$	13,998	$	10,974	$	12,082
	CECONY	$	11,214	$	12,846	$	9,841	$	10,797

Pension_Benefits_Tables

Pension Benefits (Tables) (Pension Benefits [Member])	12 Months Ended
	Dec. 31, 2014
Pension Benefits [Member]
Net Periodic Benefit Costs	The components of the Companies’ total periodic benefit costs for 2014, 2013 and 2012 were as follows:
			Con Edison									CECONY
	(Millions of Dollars)		2014			2013			2012			2014			2013			2012
	Service cost – including administrative expenses		$	227		$	267		$	237		$	211		$	249		$	220
	Interest cost on projected benefit obligation			572			537			547			536			503			513
	Expected return on plan assets			(832	)		(750	)		(705	)		(789	)		(713	)		(670	)
	Recognition of net actuarial loss			618			832			709			586			788			670
	Recognition of prior service costs			4			5			8			2			4			6
	NET PERIODIC BENEFIT COST		$	589		$	891		$	796		$	546		$	831		$	739
	Amortization of regulatory asset*			2			2			2			2			2			2
	TOTAL PERIODIC BENEFIT COST		$	591		$	893		$	798		$	548		$	833		$	741
	Cost capitalized			(225	)		(348	)		(277	)		(212	)		(327	)		(260	)
	Reconciliation to rate level			118			(84	)		(8	)		108			(87	)		(12	)
	Cost charged to operating expenses		$	484		$	461		$	513		$	444		$	419		$	469
	*	Relates to an increase in CECONY’s pension obligation of $45 million from a 1999 special retirement program.
Schedule of Funded Status	Funded Status
	The funded status at December 31, 2014, 2013 and 2012 was as follows:
			Con Edison									CECONY
	(Millions of Dollars)		2014			2013			2012			2014			2013			2012
	CHANGE IN PROJECTED BENEFIT OBLIGATION
	Projected benefit obligation at beginning of year		$	12,197		$	13,406		$	11,825		$	11,429		$	12,572		$	11,072
	Service cost – excluding administrative expenses			221			259			224			206			241			209
	Interest cost on projected benefit obligation			572			537			547			536			503			513
	Net actuarial (gain)/loss			2,641			(1,469	)		1,323			2,484			(1,388	)		1,255
	Plan amendments			6			-			-			-			-			-
	Benefits paid			(556	)		(536	)		(513	)		(518	)		(499	)		(477	)
	PROJECTED BENEFIT OBLIGATION AT END OF YEAR		$	15,081		$	12,197		$	13,406		$	14,137		$	11,429		$	12,572
	CHANGE IN PLAN ASSETS
	Fair value of plan assets at beginning of year		$	10,755		$	9,135		$	7,800		$	10,197		$	8,668		$	7,406
	Actual return on plan assets			752			1,310			1,094			715			1,241			1,040
	Employer contributions			578			879			785			535			819			729
	Benefits paid			(556	)		(536	)		(513	)		(518	)		(499	)		(477	)
	Administrative expenses			(34	)		(33	)		(31	)		(32	)		(32	)		(30	)
	FAIR VALUE OF PLAN ASSETS AT END OF YEAR		$	11,495		$	10,755		$	9,135		$	10,897		$	10,197		$	8,668
	FUNDED STATUS		$	(3,586	)	$	(1,442	)	$	(4,271	)	$	(3,240	)	$	(1,232	)	$	(3,904	)
	Unrecognized net loss		$	4,888		$	2,759		$	5,594		$	4,616		$	2,617		$	5,297
	Unrecognized prior service costs			20			17			23			4			6			10
	Accumulated benefit obligation			13,454			11,004			11,911			12,553			10,268			11,116
Schedule of Assumptions	The actuarial assumptions were as follows:
			2014			2013			2012
	Weighted-average assumptions used to determine benefit obligations at December 31:
	Discount rate			3.9	%		4.8	%		4.1	%
	Rate of compensation increase
	– CECONY			4.25	%		4.35	%		4.35	%
	– O&R			4	%		4.25	%		4.25	%
	Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
	Discount rate			4.8	%		4.1	%		4.7	%
	Expected return on plan assets			8	%		8	%		8	%
	Rate of compensation increase
	– CECONY			4.35	%		4.35	%		4.35	%
	– O&R			4.25	%		4.25	%		4.25	%
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)		2015			2016			2017			2018			2019			2020-2024
	Con Edison		$	592		$	615		$	636		$	658		$	678		$	3,642
	CECONY			552			574			594			613			632			3,388
Schedule of Plan Assets Allocations	The asset allocations for the pension plan at the end of 2014, 2013 and 2012, and the target allocation for 2015 are as follows:
			Target			Plan Assets at December 31,
			Allocation Range
	Asset Category		2015			2014			2013			2012
	Equity Securities			55% - 65%			58	%		60	%		60	%
	Debt Securities			27% - 33%			32	%		30	%		31	%
	Real Estate			8% - 12%			10	%		10	%		9	%
	Total			100%			100	%		100	%		100	%
Schedule of Fair Value of Plan Assets	The fair values of the pension plan assets at December 31, 2014 by asset category are as follows:
	(Millions of Dollars)		Level 1			Level 2			Level 3			Total
	U.S. Equity(a)		$	3,168		$	-		$	-		$	3,168
	International Equity(b)			2,841			361			-			3,202
	Private Equity(c)			-			-			114			114
	U.S. Government Issued Debt(d)			-			2,113			-			2,113
	Corporate Bonds Debt(e)			-			1,351			-			1,351
	Structured Assets Debt(f)			-			4			-			4
	Other Fixed Income Debt(g)			-			208			-			208
	Real Estate(h)			-			-			1,137			1,137
	Cash and Cash Equivalents(i)			188			477			-			665
	Futures(j)			192			37			-			229
	Hedge Funds(k)			-			-			224			224
	Total investments		$	6,389		$	4,551		$	1,475		$	12,415
	Funds for retiree health benefits(l)			(184	)		(131	)		(43	)		(358	)
	Investments (excluding funds for retiree health benefits)		$	6,205		$	4,420		$	1,432		$	12,057
	Pending activities(m)												(562	)
	Total fair value of plan net assets											$	11,495
	(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)	Private Equity consists of global equity funds that are not exchange-traded.
	(d)	U.S. Government Issued Debt includes agency and treasury securities.
	(e)	Corporate Bonds Debt consists of debt issued by various corporations.
	(f)	Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations.
	(g)	Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments.
	(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.
	(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.
	(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.
	(k)	Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.
	(l)	The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F.
	(m)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.
	The fair values of the pension plan assets at December 31, 2013 by asset category are as follows:
	(Millions of Dollars)		Level 1			Level 2			Level 3			Total
	U.S. Equity(a)		$	3,057		$	-		$	-		$	3,057
	International Equity(b)			2,303			871			-			3,174
	Private Equity(c)			-			-			67			67
	U.S. Government Issued Debt(d)			-			1,855			-			1,855
	Corporate Bonds Debt(e)			-			1,151			-			1,151
	Structured Assets Debt(f)			-			4			-			4
	Other Fixed Income Debt(g)			-			150			-			150
	Real Estate(h)			-			-			1,062			1,062
	Cash and Cash Equivalents(i)			127			558			-			685
	Futures(j)			348			-			-			348
	Hedge Funds(k)			-			-			206			206
	Total investments		$	5,835		$	4,589		$	1,335		$	11,759
	Funds for retiree health benefits(l)			(185	)		(145	)		(42	)		(372	)
	Investments(excluding funds for retiree health benefits)		$	5,650		$	4,444		$	1,293		$	11,387
	Pending activities(m)												(632	)
	Total fair value of plan net assets											$	10,755
	(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)	Private Equity consists of global equity funds that are not exchange-traded.
	(d)	U.S. Government Issued Debt includes agency and treasury securities.
	(e)	Corporate Bonds Debt consists of debt issued by various corporations.
	(f)	Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations.
	(g)	Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments.
	(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.
	(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.
	(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.
	(k)	Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.
	(l)	The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F.
	(m)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.
Reconciliation of Fair Value Balances for Net Assets	The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2014 classified as Level 3 in the fair value hierarchy.
	(Millions of Dollars)		Beginning			Assets Still Held			Assets Sold			Purchases			Transfer			Ending
			Balance as of			at Reporting Date –			During the			Sales and			In/(Out) of			Balance as of
			January 1, 2014			Unrealized Gains/			Year – Realized			Settlements			Level 3			December 31,
						(Losses)			Gains/(Losses)									2014
	Real Estate		$	1,062		$	86		$	20		$	(31	)	$	-		$	1,137
	Private Equity			67			12			-			35			-			114
	Hedge Funds			206			11			-			7			-			224
	Total investments		$	1,335		$	109		$	20		$	11		$	-		$	1,475
	Funds for retiree health benefits			(42	)		(1	)		-			-			-			(43	)
	Investments (excluding funds for retiree health benefits)		$	1,293		$	108		$	20		$	11		$	-		$	1,432
	The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2013 classified as Level 3 in the fair value hierarchy.
	(Millions of Dollars)		Beginning			Assets Still Held			Assets Sold			Purchases			Transfer			Ending
			Balance as of			at Reporting Date –			During the			Sales and			In/(Out) of			Balance as of
			January 1, 2013			Unrealized			Year – Realized			Settlements			Level 3			December 31,
						Gains/(Losses)			Gains/(Losses)									2013
	Real Estate		$	833		$	114		$	1		$	114		$	-		$	1,062
	Private Equity			20			5			-			42			-			67
	Hedge Funds			-			6			-			200			-			206
	Total investments		$	853		$	125		$	1		$	356		$	-		$	1,335
	Funds for retiree health benefits			(31	)		(3	)		-			(8	)		-			(42	)
	Investments (excluding funds for retiree health benefits)		$	822		$	122		$	1		$	348		$	-		$	1,293
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)		2014			2013			2012
	Con Edison		$	32		$	30		$	23
	CECONY			27			26			21

Other_Postretirement_Benefits_

Other Postretirement Benefits (Tables) (Other Postretirement Benefits [Member])	12 Months Ended
	Dec. 31, 2014
Other Postretirement Benefits [Member]
Net Periodic Benefit Costs	The components of the Companies’ net periodic postretirement benefit costs for 2014, 2013 and 2012 were as follows:
			Con Edison												CECONY
	(Millions of Dollars)		2014				2013				2012				2014			2013			2012
	Service cost		$	19			$	23			$	26			$	15		$	18		$	21
	Interest cost on accumulated other postretirement benefit obligation			60				54				73				52			46			63
	Expected return on plan assets			(77	)			(77	)			(85	)			(68	)		(68	)		(75	)
	Recognition of net actuarial loss			57				65				98				51			57			87
	Recognition of prior service cost			(19	)			(27	)			(21	)			(15	)		(23	)		(18	)
	Recognition of transition obligation			-				-				2				-			-			2
	NET PERIODIC POSTRETIREMENT BENEFIT COST		$	40			$	38			$	93			$	35		$	30		$	80
	Cost capitalized			(15	)			(15	)			(32	)			(14	)		(12	)		(28	)
	Reconciliation to rate level			10				58				20				2			50			16
	Cost charged to operating expenses		$	35			$	81			$	81			$	23		$	68		$	68
Schedule of Funded Status	The funded status of the programs at December 31, 2014, 2013 and 2012 were as follows:
			Con Edison												CECONY
	(Millions of Dollars)		2014				2013				2012				2014			2013			2012
	CHANGE IN BENEFIT OBLIGATION
	Benefit obligation at beginning of year		$	1,395			$	1,454			$	1,756			$	1,198		$	1,238		$	1,511
	Service cost			19				23				26				15			18			21
	Interest cost on accumulated postretirement benefit obligation			60				54				73				52			46			63
	Amendments			(12	)			-				(127	)			-			-			(89	)
	Net actuarial loss/(gain)			47				(42	)			(175	)			28			(20	)		(178	)
	Benefits paid and administrative expenses			(134	)			(136	)			(146	)			(125	)		(126	)		(134	)
	Participant contributions			36				38				37				35			38			36
	Medicare prescription subsidy			-				4				10				-			4			8
	BENEFIT OBLIGATION AT END OF YEAR		$	1,411			$	1,395			$	1,454			$	1,203		$	1,198		$	1,238
	CHANGE IN PLAN ASSETS
	Fair value of plan assets at beginning of year		$	1,113			$	1,047			$	947			$	977		$	922		$	840
	Actual return on plan assets			59				153				124				54			134			109
	Employer contributions			7				9				83				7			9			71
	EGWP payments			12				8				-				11			7			-
	Participant contributions			36				38				37				35			38			36
	Benefits paid			(143	)			(142	)			(144	)			(134	)		(133	)		(134	)
	FAIR VALUE OF PLAN ASSETS AT END OF YEAR		$	1,084			$	1,113			$	1,047			$	950		$	977		$	922
	FUNDED STATUS		$	(327	)		$	(282	)		$	(407	)		$	(253	)	$	(221	)	$	(316	)
	Unrecognized net loss		$	78			$	70			$	251			$	45		$	54		$	197
	Unrecognized prior service costs			(71	)			(78	)			(105	)			(46	)		(61	)		(84	)
Schedule of Actuarial Assumptions	The actuarial assumptions were as follows:
			2014				2013				2012
	Weighted-average assumptions used to determine benefit obligations at December 31:
	Discount Rate
	CECONY			3.75	%			4.5	%			3.75	%
	O&R			3.85	%			4.75	%			4.05	%
	Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
	Discount Rate
	CECONY			4.5	%			3.75	%			4.55	%
	O&R			4.75	%			4.05	%			4.55	%
	Expected Return on Plan Assets			7.75	%			7.75	%			8.5	%
Schedule of Change of Assumed Health Care Cost Trend Rate	A one-percentage point change in the assumed health care cost trend rate would have the following effects at December 31, 2015:
			Con Edison								CECONY
			1-Percentage-Point
	(Millions of Dollars)		Increase				Decrease				Increase				Decrease
	Effect on accumulated other postretirement benefit obligation		$	(21	)		$	40			$	(43	)		$	57
	Effect on service cost and interest cost components for 2014			(2	)			1				(4	)			3
Schedule of 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:
	(Millions of Dollars)		2015				2016				2017				2018			2019			2020-2024
	BENEFIT PAYMENTS
	Con Edison		$	99			$	95			$	94			$	92		$	89		$	419
	CECONY			89				85				84				82			79			364
Schedule of Plan Assets Allocations	The asset allocations for CECONY’s other postretirement benefit plans at the end of 2014, 2013 and 2012, and the target allocation for 2015 are as follows:
			Target Allocation Range		Plan Assets at
					December 31
	Asset Category		2015		2014				2013				2012
	Equity Securities		57% - 73%			59	%			61	%			62%
	Debt Securities		26% - 44%			41	%			39	%			38%
	Total		100%			100	%			100	%			100%
Schedule of Fair Values of Plan Assets	The fair values of the plan assets at December 31, 2014 by asset category as defined by the accounting rules for fair value measurements (see Note P) are as follows:
	(Millions of Dollars)		Level 1				Level 2				Level 3				Total
	Equity(a)		$	-			$	428			$	-			$	428
	Other Fixed Income Debt(b)			-				286				-				286
	Cash and Cash Equivalents(c)			-				11				-				11
	Total investments		$	-			$	725			$	-			$	725
	Funds for retiree health benefits(d)			184				131				43				358
	Investments(including funds for retiree health benefits)		$	184			$	856			$	43			$	1,083
	Pending activities(e)															1
	Total fair value of plan net assets														$	1,084
	(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 Barclays Capital Aggregate 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)	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 plan assets at December 31, 2013 by asset category (see Note P) are as follows:
	(Millions of Dollars)		Level 1				Level 2				Level 3				Total
	Equity(a)		$	-			$	450			$	-			$	450
	Other Fixed Income Debt(b)			-				286				-				286
	Cash and Cash Equivalents(c)			-				7				-				7
	Total investments		$	-			$	743			$	-			$	743
	Funds for retiree health benefits(d)			185				145				42				372
	Investments(including funds for retiree health benefits)		$	185			$	888			$	42			$	1,115
	Pending activities(e)															(2	)
	Total fair value of plan net assets														$	1,113
	(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 Barclays Capital Aggregate 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)	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.
Reconciliation of Fair Value Balances for Net Assets	The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2014 classified as Level 3 in the fair value hierarchy.
	(Millions of Dollars)		Beginning				Assets Still Held				Assets Sold				Purchases			Transfers			Ending
			Balance as of				at Reporting Date –				During the				Sales and			In/(Out) of			Balance as of
			January 1, 2014				Unrealized				Year – Realized				Settlements			Level 3			December 31,
							Gains/(Losses)				Gains/(Losses)										2014
	Total investments		$	-			$	-			$	-			$	-		$	-		$	-
	Funds for retiree health benefits			42				1				-				-			-			43
	Investments (including funds for retiree health benefits)		$	42			$	1			$	-			$	-		$	-		$	43
	The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2013 classified as Level 3 in the fair value hierarchy.
	(Millions of Dollars)		Beginning				Assets Still Held				Assets Sold				Purchases			Transfers			Ending
			Balance as of				at Reporting Date –				During the				Sales and			In/(Out) of			Balance as of
			January 1, 2013				Unrealized				Year – Realized				Settlements			Level 3			December 31,
							Gains/(Losses)				Gains/(Losses)										2013
	Total investments		$	-			$	-			$	-			$	-		$	-		$	-
	Funds for retiree health benefits			31				3				-				8			-			42
	Investments (including funds for retiree health benefits)		$	31			$	3			$	-			$	8		$	-		$	42

Environmental_Matters_Tables

Environmental Matters (Tables)	12 Months Ended
	Dec. 31, 2014
Environmental Remediation Obligations [Abstract]
Accrued Liabilities and Regulatory Assets	The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Accrued Liabilities:
	Manufactured gas plant sites		$	684	$	665	$	587	$	562
	Other Superfund Sites			80		84		79		82
	Total		$	764	$	749	$	666	$	644
	Regulatory assets		$	925	$	938	$	820	$	830
Environmental Remediation Costs	Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites at December 31, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Remediation costs incurred		$	29	$	41	$	20	$	35
	Insurance recoveries received*			7		-		7		-
	*	Reduced amount deferred for recovery from customers
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, 2014 and 2013 were as follows:
			Con Edison				CECONY
	(Millions of Dollars)		2014		2013		2014		2013
	Accrued liability – asbestos suits		$	8	$	8	$	7	$	7
	Regulatory assets – asbestos suits		$	8	$	8	$	7	$	7
	Accrued liability – workers’ compensation		$	83	$	87	$	78	$	82
	Regulatory assets – workers’ compensation		$	8	$	12	$	8	$	12

Other_Material_Contingencies_T

Other Material Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Total Guarantees	A summary, by type and term, of Con Edison’s total guarantees at December 31, 2014 is as follows:
	Guarantee Type	0 – 3		4 – 10		> 10		Total
		years		years		years
		(Millions of Dollars)
	NY Transco	$	1,361	$	-	$	-	$	1,361
	Energy transactions		774		31		96		901
	Renewable electric production projects		248		-		7		255
	Other		30		-		-		30
	Total	$	2,413	$	31	$	103	$	2,547

Electricity_Purchase_Agreement1

Electricity Purchase Agreements (Tables)	12 Months Ended
	Dec. 31, 2014
Regulated Operations [Abstract]
Summary of Significant Terms of Electricity Purchase Agreements	At December 31, 2014, the significant terms of the electricity purchase agreements were as follows:
	Facility		Equity Owner		Plant				Contracted				Contract				Contract
					Output				Output				Start				Term
					(MW)				(MW)				Date				(Years)
	Brooklyn Navy Yard		Brooklyn Navy Yard Cogeneration Partners, LP			322				291				November 1996				40
	Linden Cogeneration		Cogen Technologies Linden Venture, LP			1,035				607				May-92				25
	Indeck Corinth		Indeck Energy Services of Corinth, Inc.			147				131				Jul-95				20
	Indian Point		Entergy Nuclear Power Marketing, LLC			2,311				500				August 2001				16
	Astoria Energy		Astoria Energy, LLC			640				500				May-06				10
Summary of Estimated Capacity and Other Fixed Payments	The future capacity and other fixed payments under the contracts are estimated to be as follows:
	(Millions of		2015				2016				2017				2018				2019		All Years
	Dollars)																				Thereafter
	CECONY		$	252			$	186			$	135			$	62			$	53	$	820
Summary of Capacity, Energy and Other Fixed Payments	The company’s payments under the agreements for capacity, energy and other fixed payments in 2014, 2013 and 2012 were as follows:
			For the Years Ended
			December 31,
	(Millions of Dollars)		2014				2013				2012
	Brooklyn Navy Yard		$	133			$	118			$	93
	Linden Cogeneration			381				346				297
	Indeck Corinth			80				79				66
	Indian Point			247				220				204
	Astoria Energy			230				183				181
	Selkirk*			144				215				196
	Independence*			97				121				127
	Total		$	1,312			$	1,282			$	1,164
	*	Contract term ended in 2014

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Schedule of Capital Leases	The following assets under capital leases are included in the Companies’ consolidated balance sheets at December 31, 2014 and 2013:
		Con Edison					CECONY
	(Millions of Dollars)	2014		2013			2014		2013
	UTILITY PLANT
	Common	$	3	$	3		$	1	$	2
Future Minimum Lease Commitments	The future minimum lease commitments for the above assets are as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	1	$	1
	2016		1		1
	2017		-		-
	2018		-		-
	2019		-		-
	All years thereafter		-		-
	Total		2		2
	Less: amount representing interest		1		1
	Present value of net minimum lease payment	$	1	$	1
Future Minimum Rental Payments for Operating Leases	The future minimum lease commitments under the Companies’ non-cancelable operating lease agreements are as follows:
	(Millions of Dollars)	Con Edison		CECONY
	2015	$	18	$	14
	2016		17		13
	2017		16		12
	2018		16		12
	2019		14		10
	All years thereafter		72		51
	Total	$	153	$	112
Schedule of Leveraged Lease Transactions Effect on Consolidated Income Statement	The effect on Con Edison’s consolidated income statement for the twelve months ended as of December 31, 2014 and 2013 was as follows:
		For the Years Ended
		December 31,
	(Millions of Dollars)	2014		2013
	Increase/(decrease) to non-utility operating revenues	$	-	$	(27	)
	(Increase)/decrease to other interest expense		13		(131	)
	Income tax benefit/(expense)		-14		63
	Total increase/(decrease) in net income		($1)		($95)

Income_Tax_Tables

Income Tax (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax	The components of income tax are as follows:
		Con Edison									CECONY
	(Millions of Dollars)	2014			2013			2012			2014			2013			2012
	State
	Current	$	59		$	151		$	29		$	66		$	111		$	53
	Deferred		61			(70	)		97			65			(14	)		53
	Federal
	Current		(9	)		285			(13	)		158			187			110
	Deferred		463			115			493			271			241			318
	Amortization of investment tax credits		(6	)		(5	)		(6	)		(5	)		(5	)		(5	)
	Total income tax expense	$	568		$	476		$	600		$	555		$	520		$	529
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)	2014			2013			2014			2013
	Deferred tax liabilities:
	Property basis differences	$	7,510		$	7,012		$	6,938		$	6,424
	Unrecognized pension and other postretirement costs		1,968			1,109			1,872			1,060
	Regulatory asset – future income tax		910			871			863			825
	Environmental remediation costs		376			381			333			337
	Deferred storm costs		129			179			91			136
	Equity investments		168			21			-			-
	Other regulatory assets		347			402			300			364
	Unamortized investment tax credits		126			43			37			42
	Total deferred tax liabilities and investment tax credits		11,534			10,018			10,434			9,188
	Deferred tax assets:
	Accrued pension and other postretirement costs		1,306			458			1,155			364
	Regulatory liabilities		615			604			574			569
	Superfund and other environmental costs		306			301			264			256
	Asset retirement obligations		77			58			75			58
	Loss carryforwards		21			12			-			-
	Loss carryforwards, valuation reserve		(11	)		(12	)		-			-
	Other		272			253			203			209
	Total deferred tax assets		2,586			1,674			2,271			1,456
	Net deferred tax liabilities and investment tax credits	$	8,948		$	8,344		$	8,163		$	7,732
	Deferred income taxes and investment tax credits – noncurrent	$	9,076		$	8,466		$	8,257		$	7,832
	Deferred tax assets – current		(128	)		(122	)		(94	)		(100	)
	Net deferred tax liabilities and investment tax credits	$	8,948		$	8,344		$	8,163		$	7,732
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)	2014			2013			2012			2014			2013			2012
	STATUTORY TAX RATE
	Federal		35	%		35	%		35	%		35	%		35	%		35	%
	Changes in computed taxes resulting from:
	State income tax		5			4			4			5			5			4
	Cost of removal		(5	)		(5	)		(4	)		(5	)		(5	)		(4	)
	Manufacturing deduction		-			(1	)		-			-			-			-
	Other		(1	)		(2	)		(1	)		(1	)		(1	)		(1	)
	Effective tax rate		34	%		31	%		34	%		34	%		34	%		34	%
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)	2014			2013			2012			2014			2013			2012
	Balance at January 1,	$	9		$	86		$	130		$	-		$	74		$	114
	Additions based on tax positions related to the current year		-			5			12			-			-			11
	Additions based on tax positions of prior years		27			253			-			2			-			-
	Reductions for tax positions of prior years		(2	)		(86	)		(57	)		-			(74	)		(52	)
	Settlements		-			(249	)		1			-			-			1
	Balance at December 31,	$	34		$	9		$	86		$	2		$	-		$	74

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Stock-Based Compensation Expense	The following table summarizes stock-based compensation expense recognized by the Companies in the years ended December 31, 2014, 2013 and 2012:
			Con Edison								CECONY
	(Millions of Dollars)		2014			2013		2012			2014			2013		2012
	Performance-based restricted stock		$	22		$	20	$	14		$	19		$	18	$	13
	Time-based restricted stock			2			2		1			2			2		1
	Non-employee director deferred stock compensation			2			2		1			2			2		1
	Stock purchase plan			3			3		3			3			3		3
	Total		$	29		$	27	$	19		$	26		$	25	$	18
	Income tax benefit		$	12		$	11	$	8		$	10		$	10	$	7
Summary of Status of Stock Options	A summary of changes in the status of stock options as of December 31, 2014 is as follows:
			Con Edison								CECONY
			Shares			Weighted		Shares			Weighted
						Average					Average
						Exercise					Exercise
						Price					Price
	Outstanding at 12/31/13			481,310		$	43.38		381,010		$	43.34
	Exercised			(251,460	)		43.75		(189,660	)		43.68
	Forfeited			-			-		-			-
	Outstanding at 12/31/14			229,850		$	42.99		191,350		$	43
	Note: The weighted average remaining contractual life is one year for all outstanding options as of 12/31/14.
Summary of Stock Options	The following table summarizes information about stock options for the years ended December 31, 2014 and 2013:
			Con Edison					CECONY
	(Millions of Dollars)		2014			2013		2014			2013
	Aggregate intrinsic value*
	Options outstanding		$	5		$	6	$	4		$	5
	Options exercised			4			2		3			2
	Cash received by Con Edison for			11			5		8			4
	payment of exercise price
	*	Aggregate intrinsic value represents the changes in the fair value of all outstanding options from their grant dates to December 31 of the years presented above.
Assumptions Used to Calculate Fair Value	The following table illustrates the assumptions used to calculate the fair value of the awards:
			2014			2013		2012
	Risk-free interest rate(a)			0.23% - 3.07%			0.13% - 5.17%		0.15% - 3.39%
	Expected term(b)			3 years			3 years		3 years
	Expected share price volatility(c)			13.14%			13.52%		15.27%
	(a)	The risk-free rate is based on the U.S. Treasury zero-coupon yield curve on the date of grant.
	(b)	The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur.
	(c)	The expected volatility is calculated using daily closing stock prices over a period of three years, which approximates the expected term of the awards.
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, 2014 is as follows:
			Con Edison					CECONY
			Units			Weighted		Units			Weighted
						Average					Average
						Grant					Grant
						Date Fair					Date Fair
						Value					Value
	Non-vested at 12/31/13			66,580		$	56.92		63,030		$	56.93
	Granted			22,990			53.65		21,790			53.65
	Vested			(20,900	)		50.74		(19,800	)		50.75
	Forfeited			(3,247	)		58.06		(2,847	)		58.27
	Non-vested at 12/31/14			65,423		$	57.65		62,173		$	57.64
Tsr and non-tsr portions.
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, 2014 is as follows:
			Con Edison								CECONY
			Units			Weighted					Units			Weighted
						Average								Average
						Grant Date								Grant Date
						Fair Value(a)								Fair Value(a)
						TSR		Non-TSR						TSR		Non-TSR
						Portion(b)		Portion(c)						Portion(b)		Portion(c)
	Non-vested at 12/31/13			1,121,598		$	49.32	$	55.31			897,052		$	49.38	$	55.42
	Granted			428,310			25.34		53.65			342,001			25.86		53.71
	Vested			(411,704	)		43.84		50.05			(323,483	)		43.93		50.08
	Forfeited			(37,597	)		40.9		55.97			(35,047	)		40.84		55.95
	Non-vested at 12/31/14			1,100,607		$	42.33	$	56.61			880,523		$	42.58	$	56.7
	(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.

Financial_Information_by_Busin1

Financial Information by Business Segment (Tables)	12 Months Ended
	Dec. 31, 2014
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		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2014		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,437		$	16		$	781		$	1,712		$	412		$	425		$	30,421	$	1,500
	Gas			1,721			6			132			314			89			88			6,530		549
	Steam			628			84			78			113			36			49			2,686		83
	Consolidation adjustments			-			(106	)		-			-			-			-			-		-
	Total CECONY		$	10,786		$	-		$	991		$	2,139		$	537		$	562		$	39,637	$	2,132
	O&R
	Electric		$	680		$	-		$	46		$	103		$	24		$	29		$	2,042	$	105
	Gas			212			-			15			25			10			6			794		37
	Other(b)			-			-			-			-			1			-			1		-
	Total O&R		$	892		$	-		$	61		$	128		$	35		$	35		$	2,837	$	142
	Competitive energy businesses		$	1,244		$	(10	)	$	19		$	(60	)	$	(8	)	$	(8	)	$	1,026	$	447
	Other(c)			(3	)		10			-			2			27			-			808		-
	Total Con Edison		$	12,919		$	-		$	1,071		$	2,209		$	591		$	589		$	44,308	$	2,721
	As of and for the Year Ended		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2013		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,131		$	16		$	749		$	1,595		$	402		$	380		$	27,673	$	1,471
	Gas			1,616			5			130			362			83			112			6,008		536
	Steam			683			82			67			103			36			39			2,577		128
	Consolidation adjustments			-			(103	)		-			-			-			-			-		-
	Total CECONY		$	10,430		$	-		$	946		$	2,060		$	521		$	531		$	36,258	$	2,135
	O&R
	Electric		$	628		$	-		$	41		$	87		$	25		$	13		$	1,898	$	98
	Gas			205			-			15			33			11			7			645		37
	Other(b)			-			-			-			-			1			-			2		-
	Total O&R		$	833		$	-		$	56		$	120		$	37		$	20		$	2,545	$	135
	Competitive energy businesses		$	1,096		$	5		$	23		$	63		$	135		$	(41	)	$	1,314	$	378
	Other(c)			(5	)		(5	)		(1	)		1			26			(6	)		530		-
	Total Con Edison		$	12,354		$	-		$	1,024		$	2,244		$	719		$	504		$	40,647	$	2,648
	As of and for the Year Ended		Operating			Inter-			Depreciation			Operating			Interest			Income			Total		Construction
	December 31, 2012		revenues			segment			and			income			charges			taxes on			assets(b)		expenditures
	(Millions of Dollars)					revenues			amortization									operating
																		income(a)
	CECONY
	Electric		$	8,176		$	15		$	710		$	1,693		$	423		$	393		$	28,339	$	1,375
	Gas			1,415			5			120			346			82			99			5,925		426
	Steam			596			77			64			54			40			22			2,621		108
	Consolidation adjustments			-			(97	)		-			-			-			-			-		-
	Total CECONY		$	10,187		$	-		$	894		$	2,093		$	545		$	514		$	36,885	$	1,909
	O&R
	Electric		$	592		$	-		$	38		$	83		$	19		$	17		$	1,960	$	98
	Gas			203			-			15			40			10			11			706		39
	Other(b)			-			-			-			-			2			-			5		-
	Total O&R		$	795		$	-		$	53		$	123		$	31		$	28		$	2,671	$	137
	Competitive energy businesses		$	1,213		$	8		$	8		$	125		$	1		$	52		$	1,061	$	492
	Other(c)			(7	)		(8	)		-			(2	)		27			-			592		-
	Total Con Edison		$	12,188		$	-		$	955		$	2,339		$	604		$	594		$	41,209	$	2,538
	(a)	For Con Edison, income taxes on non-operating income were $(21), $(28) and $6 million in 2014, 2013 and 2012, respectively. For CECONY, income taxes on non-operating income were $(7), $(11) and $15 million in 2014, 2013 and 2012, respectively.
	(b)	Includes amounts related to the RECO securitization.
	(c)	Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities	The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at December 31, 2014 and 2013 were:
	(Millions of Dollars)		2014												2013
	Balance Sheet Location		Gross				Gross				Net Amounts				Gross				Gross			Net Amounts
			Amounts of				Amounts				of Assets/				Amounts of				Amounts			of Assets/
			Recognized				Offset				(Liabilities)(a)				Recognized				Offset			(Liabilities)(a)
			Assets/												Assets/
			(Liabilities)												(Liabilities)
	Con Edison
	Fair value of derivative assets
	Current		$	111			$	(67	)		$	44	(b)		$	134			$	(77	)	$	57	(b)
	Non-current			34				(23	)			11				32				(24	)		8
	Total fair value of derivative assets		$	145			$	(90	)		$	55			$	166			$	(101	)	$	65
	Fair value of derivative liabilities
	Current		$	(242	)		$	139			$	(103	)		$	(82	)		$	72		$	(10	)
	Non-current			(66	)			91				25				(31	)			26			(5	)
	Total fair value of derivative liabilities		$	(308	)		$	230			$	(78	)		$	(113	)		$	98		$	(15	)
	Net fair value derivative assets/(liabilities)		$	(163	)		$	140			$	(23	)(b)		$	53			$	(3	)	$	50	(b)
	CECONY
	Fair value of derivative assets
	Current		$	26			$	(15	)		$	11	(b)		$	27			$	(19	)	$	8	(b)
	Non-current			22				(20	)			2				14				(13	)		1
	Total fair value of derivative assets		$	48			$	(35	)		$	13			$	41			$	(32	)	$	9
	Fair value of derivative liabilities
	Current		$	(96	)		$	48			$	(48	)		$	(32	)		$	21		$	(11	)
	Non-current liabilities			(42	)			32				(10	)			(19	)			16			(3	)
	Total fair value of derivative liabilities		$	(138	)		$	80			$	(58	)		$	(51	)		$	37		$	(14	)
	Net fair value derivative assets/(liabilities)		$	(90	)		$	45			$	(45	)(b)		$	(10	)		$	5		$	(5	)(b)
	(a)	Derivative instruments and collateral were set off 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 setoff in the event of contract termination. In such case, generally the non-defaulting party’s payable will be set-off 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, 2014 and 2013, margin deposits for Con Edison ($27 million and $17 million, respectively) and CECONY ($25 million and $16 million, respectively) were classified as derivative assets in the 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.
Realized and Unrealized Gains or Losses on Commodity Derivatives	The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the years ended December 31, 2014 and 2013:
					Con Edison								CECONY
	(Millions of Dollars)		Balance Sheet Location		2014				2013				2014				2013
	Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
	Current		Deferred derivative gains		$	(10	)		$	14			$	(7	)		$	11
	Long-term		Deferred derivative gains			1				-				1				-
	Total deferred gains/(losses)				$	(9	)		$	14			$	(6	)		$	11
	Current		Deferred derivative losses		$	(75	)		$	47			$	(70	)		$	38
	Current		Recoverable energy costs			36				(39	)			26				(37	)
	Long-term		Deferred derivative losses			(17	)			27				(17	)			13
	Total deferred gains/(losses)				$	(56	)		$	35			$	(61	)		$	14
	Net deferred gains/(losses)				$	(65	)		$	49			$	(67	)		$	25
			Income Statement Location
	Pre-tax gain/(loss) recognized in income
			Purchased power expense		$	(37	)(a)		$	90	(a)		$	-			$	-
			Gas purchased for resale			(115	)			(27	)			-				-
			Non-utility revenue			29	(a)			9	(a)			-				-
	Total pre-tax gain/(loss) recognized in income				$	(123	)		$	72			$	-			$	-
	(a)	Con Edison recorded unrealized gains and losses in non-utility operating revenue ($4 million gain and an immaterial gain) and purchased power expense ($132 million loss and $74 million gain) for the years ended December 31, 2014 and 2013, respectively.
Hedged Volume of Derivative Transactions	The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at December 31, 2014:
			Electric Energy (MWHs)(a)(b)				Capacity (MWs)(a)				Natural Gas (Dt)(a)(b)
	Con Edison			17,792,555				7,706				66,793,011
	CECONY			5,543,250				2,100				62,065,000
	(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, 2014:
	(Millions of Dollars)		Con Edison(a)				CECONY(a)
	Aggregate fair value – net liabilities		$	78			$	58
	Collateral posted		$	1			$	-
	Additional collateral(b) (downgrade one level from current ratings)		$	6			$	2
	Additional collateral(b) (downgrade to below investment grade from current ratings)		$	105	(c)		$	63	(c)
	(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 Con Edison’s competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post collateral, which at December 31, 2014, would have amounted to an estimated $16 million for Con Edison, including $3 million for CECONY. 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 liabilities 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 of setoff.
	(c)	Derivative instruments that are net assets have been excluded from the table. At December 31, 2014, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $15 million.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value on Recurring Basis	Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2014 and 2013 are summarized below.
			2014														2013
	(Millions of Dollars)		Level 1			Level 2			Level 3			Netting			Total		Level 1		Level 2		Level 3		Netting			Total
												Adjustment(e)											Adjustment(e)
	Con Edison
	Derivative assets:
	Commodity(a)(b)(c)		$	3		$	78		$	28		$	(27	)	$	82	$	3	$	130	$	11	$	(62	)	$	82
	Other(a)(b)(d)			163			116			-			-			279		141		113		-		-			254
	Total assets		$	166		$	194		$	28		$	(27	)	$	361	$	144	$	243	$	11	$	(62	)	$	336
	Derivative liabilities:
	Commodity(a)(b)(c)		$	18		$	246		$	8		$	(194	)	$	78	$	5	$	84	$	2	$	(76	)	$	15
	Interest rate contract(a)(b)			-			-			-			-			-		-		2		-		-			2
	Total liabilities		$	18		$	246		$	8		$	(194	)	$	78	$	5	$	86	$	2	$	(76	)	$	17
	CECONY
	Derivative assets
	Commodity(a)(b)(c)		$	1		$	3		$	13		$	21		$	38	$	3	$	13	$	6	$	3		$	25
	Other(a)(b)(d)			155			106			-			-			261		134		103		-		-			237
	Total assets		$	156		$	109		$	13		$	21		$	299	$	137	$	116	$	6	$	3		$	262
	Derivative liabilities:
	Commodity(a)(b)(c)		$	16		$	91		$	-		$	(49	)	$	58	$	5	$	27	$	-	$	(18	)	$	14
	Total Liabilities		$	16		$	91		$	-		$	(49	)	$	58	$	5	$	27	$	-	$	(18	)	$	14
	(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. There were no transfers between levels 1, 2 and 3 for the years ended December 31, 2014 and 2013.
	(b)	Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, interest rate swap, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, and certain over-the-counter derivative instruments for electricity 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, 2014 and 2013, 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.
Schedule of Commodity Derivatives	The risk management group reports to the Companies’ Vice President and Treasurer.
			Fair Value of Level 3 at			Valuation		Unobservable Inputs	Range
			December 31, 2014			Techniques
			(Millions of Dollars)
	Con Edison – Commodity
	Electricity		$	1		Discounted Cash Flow		Forward energy prices(a)	$22.59 - $119.75 per MWH
						Discounted Cash Flow		Forward capacity prices(a)	$1.00 - $8.80 per kW -  month
	Natural Gas			2		Discounted Cash Flow		Forward gas prices(a)	$(1.64) - $5.00 per Dt
	Transmission Congestion Contracts / Financial Transmission Rights			17		Discounted Cash Flow		Discount to adjust auction prices for inter-zonal forward price curves(b)	9.6% - 57.9%
								Discount to adjust auction prices for historical monthly realized settlements(b)	32.3% - 56.1%
								Inter-zonal forward price curves adjusted for historical zonal losses(b)	$(2.66) - $16.49
	Total Con Edison—Commodity		$	20
	CECONY – Commodity
	Transmission Congestion Contracts		$	13		Discounted Cash Flow		Discount to adjust auction prices for inter-zonal forward price curves(b)	9.6% - 57.9%
								Discount to adjust auction prices for historical monthly realized settlements(b)	32.3% - 56.1%
	(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, 2014 and 2013 and classified as Level 3 in the fair value hierarchy:
			Con Edison						CECONY
	(Millions of Dollars)		2014			2013			2014			2013
	Beginning Balance as of January 1,		$	9		$	(5	)	$	6		$	10
	Included in Earnings			30			7			2			7
	Included in Regulatory Assets and Liabilities			7			18			7			(1	)
	Purchases			22			17			16			13
	Settlements			(48	)		(28	)		(18	)		(23	)
	Ending Balance as of December 31,		$	20		$	9		$	13		$	6

Variable_Interest_Entities_Tab

Variable Interest Entities (Tables)	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Schedule of Sale and Deconsolidation of a Variable Interest Entity	As a result of the sale, Con Edison Development received net proceeds of $108 million and recognized a pre-tax gain on the sale of $45 million ($26 million, net of tax). The following table summarizes the sale and resultant deconsolidation on the transaction date:
	(Millions of Dollars)
	Proceeds from sale, net of transaction costs of $1		$	108
	Non-utility property, less accumulated depreciation			(341	)
	Other assets, including working capital			(31	)
	Long-term debt, including current portion			217
	Other liabilities			9
	Gain on sale of solar electric production projects			(45	)
	Equity method investment upon deconsolidation		$	(83	)
Schedule of Assets and Liabilities Included in Consolidated Balance Sheet	At December 31, 2014, Con Edison’s consolidated balance sheet includes $58 million in net assets (as detailed in the table below) and the non-controlling interest of the third party of $9 million related to Texas Solar 4. Earnings for the twelve months ended December 31, 2014 were immaterial.
	(Millions of Dollars)
	Restricted cash		$	13
	Non-utility property, less accumulated depreciation			108
	Other assets			14
	Total assets(a)		$	135
	Long-term debt due within one year		$	66
	Other liabilities			11
	Total liabilities(b)		$	77
	(a)	The assets of Texas Solar 4 represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE.
	(b)	The liabilities of Texas Solar 4 represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary.
Summary of VIEs	The following table summarizes the VIEs in which Con Edison Development has entered into as of December 31, 2014:
	Project Name(a)		Generating			Power Purchase			Year of Initial		Location		Maximum Exposure to
			Capacity			Agreement Term			Investment				Loss (In Millions)(c)
			Owned			in Years
	Pilesgrove			9			n/a	(b)		2010		New Jersey	$	26
	Mesquite Solar 1			83			20			2013		Arizona		111
	Copper Mountain Solar 2			75			25			2013		Nevada		80
	Copper Mountain Solar 3			128			20			2014		Nevada		175
	California Solar			55			25			2012		California		81
	Texas Solar 4			32			25			2014		Texas		58
	Broken Bow II			37			25			2014		Nebraska		57
	(a)	With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development.
	(b)	Pilesgrove has 3-5 year Solar Renewable Energy Credit (SREC) hedges in place.
	(c)	For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the balance sheet. For consolidated investments, maximum exposure is equal to the net assets of the investment on the balance sheet. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
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, 2014, 2013 and 2012 were as follows:
		CECONY
	(Millions of Dollars)	2014		2013		2012
	Cost of services provided	$	90	$	84	$	83
	Cost of services received	$	57	$	52	$	49

Summary_of_Significant_Account3

Summary of Significant Accounting Policies - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary Of Significant Accounting Policies [Line Items]
Annual aggregate depreciation allowance	$1,048,000,000
Impairment charges	0	0	0
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	20.00%
Non Utility Plan [Member] | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	3 years
Non Utility Plan [Member] | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	30 years
CECONY [Member]
Summary Of Significant Accounting Policies [Line Items]
AFUDC rates	1.60%	4.00%	6.50%
Average depreciation rates	3.10%	3.20%	3.10%
Annual aggregate depreciation allowance	$993,000,000
CECONY [Member] | Electric Generation [Member] | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	5 years
CECONY [Member] | Electric Generation [Member] | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	85 years
CECONY [Member] | Gas [Member] | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	5 years
CECONY [Member] | Gas [Member] | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	85 years
CECONY [Member] | Steam [Member] | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	5 years
CECONY [Member] | Steam [Member] | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	80 years
CECONY [Member] | General [Member] | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	5 years
CECONY [Member] | General [Member] | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	55 years
O&R [Member]
Summary Of Significant Accounting Policies [Line Items]
AFUDC rates	2.60%	5.70%	7.00%
Average depreciation rates	2.90%	2.80%	2.90%
O&R [Member] | Electric Generation [Member] | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	5 years
O&R [Member] | Electric Generation [Member] | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	75 years
O&R [Member] | Gas [Member] | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	5 years
O&R [Member] | Gas [Member] | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	75 years
O&R [Member] | General [Member] | Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	5 years
O&R [Member] | General [Member] | Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives, (years)	50 years

Summary_of_Significant_Account4

Summary of Significant Accounting Policies - Capitalized Cost of Utility Plant (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Public Utility, Property, Plant and Equipment [Line Items]
General	$2,465	$2,336
Held for future use	76	73
Construction work in progress	1,031	1,393
NET UTILITY PLANT	29,326	27,795
Electric Generation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Generation	451	452
Electric Transmission [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	2,956	2,776
Electric Distribution [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	16,361	15,277
Gas [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Gas	5,006	4,469
Steam [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,795	1,790
General [Member]
Public Utility, Property, Plant and Equipment [Line Items]
General	1,650	1,565
CECONY [Member]
Public Utility, Property, Plant and Equipment [Line Items]
General	2,265	2,154
Held for future use	65	62
Construction work in progress	971	1,303
NET UTILITY PLANT	27,585	26,146
CECONY [Member] | Electric Generation [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Generation	451	452
CECONY [Member] | Electric Transmission [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	2,744	2,597
CECONY [Member] | Electric Distribution [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	15,531	14,496
CECONY [Member] | Gas [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Gas	4,530	4,013
CECONY [Member] | Steam [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,795	1,790
CECONY [Member] | General [Member]
Public Utility, Property, Plant and Equipment [Line Items]
General	$1,498	$1,433

Summary_of_Significant_Account5

Summary of Significant Accounting Policies - Schedule of Total Excise Taxes Recorded in Operating Revenues (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule of Excise Taxes [Line Items]
Excise taxes	$365	$354	$334
CECONY [Member]
Schedule of Excise Taxes [Line Items]
Excise taxes	$343	$329	$306

Summary_of_Significant_Account6

Summary of Significant Accounting Policies - Research and Development Costs (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Research and Development Expenses [Line Items]
Research and Development Costs	$22	$18	$21
CECONY [Member]
Research and Development Expenses [Line Items]
Research and Development Costs	$20	$16	$19

Summary_of_Significant_Account7

Summary of Significant Accounting Policies - Earnings Per Common Share (Detail) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share [Abstract]
Net income for common stock	$1,092	$1,062	$1,138
Weighted average common shares outstanding - Basic	292.9	292.9	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.1	1.5	1.6
Adjusted weighted average common shares outstanding - Diluted	294	294.4	294.5
Net income for common stock per common share - basic	$3.73	$3.62	$3.88
Net income for common stock per common share - diluted	$3.71	$3.61	$3.86

Summary_of_Significant_Account8

Summary of Significant Accounting Policies - Changes in Accumulated Other Comprehensive Income by Component (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated OCI, net of taxes	($25)	($53)
OCI before reclassifications, net of tax	-26	21
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	6	7
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	-20	28	5
Accumulated OCI, net of taxes	-45	-25	-53
CECONY [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated OCI, net of taxes	-6	-9
OCI before reclassifications, net of tax	-6	2
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	1	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	-5	3	-1
Accumulated OCI, net of taxes	($11)	($6)	($9)

Summary_of_Significant_Account9

Summary of Significant Accounting Policies - Changes in Accumulated Other Comprehensive Income by Component (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]
OCI before reclassifications, Tax	$18	($15)
Amounts reclassified from accumulated OCI related to pension plan liabilities, Tax	-4	-5
CECONY [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
OCI before reclassifications, Tax	4	-1
Amounts reclassified from accumulated OCI related to pension plan liabilities, Tax	($1)	($1)

Regulatory_Matters_Summary_of_

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Electric) (Detail) (USD $)	9 Months Ended	12 Months Ended						36 Months Ended	1 Months Ended	12 Months Ended	24 Months Ended
	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Mar. 31, 2011	Mar. 31, 2013	Jan. 31, 2016	Dec. 31, 2015	Dec. 31, 2015
Public Utilities, General Disclosures [Line Items]
Cost reconciliations, deferred net regulatory assets	$604,000,000	$615,000,000	$604,000,000
Cost reconciliations, deferred net regulatory liabilities	871,000,000	910,000,000	871,000,000
CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Cost reconciliations, deferred net regulatory assets	569,000,000	574,000,000	569,000,000
Cost reconciliations, deferred net regulatory liabilities	825,000,000	863,000,000	825,000,000
CECONY [Member] | Electric Transmission [Member]
Public Utilities, General Disclosures [Line Items]
Deferred revenues	34,000,000		34,000,000		59,000,000
Cost reconciliations, deferred net regulatory assets	35,000,000		35,000,000
Base rate changes		-76,200,000		287,000,000		420,000,000	420,000,000
Amortizations to income of net regulatory (assets) and liabilities								-75,300,000
Deferred major storm costs		107,000,000
Retention of annual transmission congestion revenues	90,000,000	90,000,000		120,000,000		120,000,000	120,000,000
Negative revenue adjustments		5,000,000	0		0
Cost reconciliations, deferred net regulatory liabilities		57,000,000			146,000,000
Deferred regulatory liability			7,000,000		7,000,000
Average rate base		17,323,000,000		16,826,000,000		15,987,000,000	14,887,000,000
Weighted average cost of capital (after-tax)		7.05%		7.76%		7.76%	7.76%
Authorized return on common equity		9.20%		10.15%		10.15%	10.15%
Earnings sharing percentage		9.80%		10.65%		10.65%	11.15%	10.65%
Authorized return on common equity, austerity measures				13,000,000		20,000,000	27,000,000
Earnings sharing, threshold limit		0	17,500,000
Cost of long-term debt		5.17%		5.65%		5.65%	5.65%	5.65%
Common equity ratio		48.00%		48.00%		48.00%	48.00%
CECONY [Member] | Electric Transmission [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Potential penalties		400,000,000		350,000,000		350,000,000	350,000,000
CECONY [Member] | Electric Transmission [Member] | T&D [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability		16,869,000,000		15,414,000,000		14,742,000,000	13,818,000,000
CECONY [Member] | Electric Transmission [Member] | ERP [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability				115,000,000		25,000,000
CECONY [Member] | Electric Transmission [Member] | Other [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability		2,034,000,000		1,650,000,000		1,565,000,000	1,487,000,000
CECONY [Member] | Electric Transmission [Member] | Storm Hardening [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability		89,000,000
CECONY [Member] | Electric Transmission [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes										124,000,000
Amortizations to income of net regulatory (assets) and liabilities											-37,000,000
Deferred major storm costs										107,000,000	107,000,000
Retention of annual transmission congestion revenues										90,000,000
Average rate base										18,113,000,000
Weighted average cost of capital (after-tax)										7.08%
Authorized return on common equity									10.00%	9.20%
Earnings sharing percentage										9.80%	9.80%
Cost of long-term debt										5.23%	5.23%
Common equity ratio									48.00%	48.00%
CECONY [Member] | Electric Transmission [Member] | Scenario, Forecast [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Potential penalties										400,000,000
CECONY [Member] | Electric Transmission [Member] | Scenario, Forecast [Member] | T&D [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability										17,401,000,000
CECONY [Member] | Electric Transmission [Member] | Scenario, Forecast [Member] | Other [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability										2,102,000,000
CECONY [Member] | Electric Transmission [Member] | Scenario, Forecast [Member] | Storm Hardening [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability										$177,000,000

Regulatory_Matters_Summary_of_1

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Electric) (Parenthetical) (Detail) (Electric Transmission [Member], CECONY [Member], USD $)	9 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2014	Mar. 31, 2013	Dec. 31, 2015
Public Utilities, General Disclosures [Line Items]
Potential refund from customers		$249
Elimination of temporary base rate increase through credits			134
Deferrals for property taxes limitation from rates	80.00%	90.00%
Annual maximum property tax adjustment allowed on required rate of return		Not more than a 10 basis point
PJM Interconnection L.L.C. [Member]
Public Utilities, General Disclosures [Line Items]
Recovery of charges pursuant to tariff of PJM		20
Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Base rate change deferral regulatory liability impact				30
Storm Reserve [Member]
Public Utilities, General Disclosures [Line Items]
Revenue requirement		21
Storm Reserve [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Revenue requirement				$21

Regulatory_Matters_Additional_

Regulatory Matters - Additional Information (Detail) (USD $)	12 Months Ended												1 Months Ended	12 Months Ended	0 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2011	Jun. 30, 2014	Jun. 30, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011	Oct. 31, 2012	Oct. 31, 2011	Oct. 31, 2010	Jan. 31, 2016	Dec. 31, 2015	Nov. 01, 2015	Jun. 30, 2015	Dec. 31, 2016
Electric Transmission [Member] | CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Return on common equity	9.20%	10.15%	10.15%	10.15%
Common equity ratio	48.00%	48.00%	48.00%	48.00%
Electric Transmission [Member] | O&R [Member]
Public Utilities, General Disclosures [Line Items]
Return on common equity					9.50%	9.40%
Common equity ratio					48.00%	48.00%
Gas [Member] | CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Return on common equity	9.30%						9.60%	9.60%	9.60%
Common equity ratio	48.00%						48.00%	48.00%	48.00%
Gas [Member] | O&R [Member]
Public Utilities, General Disclosures [Line Items]
Return on common equity										10.40%	10.40%	10.40%
Common equity ratio										48.00%	48.00%	48.00%
Scenario, Forecast [Member] | Electric Transmission [Member] | CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Electric rate increases													$368
Return on common equity													10.00%	9.20%
Common equity ratio													48.00%	48.00%
Scenario, Forecast [Member] | Electric Transmission [Member] | O&R [Member]
Public Utilities, General Disclosures [Line Items]
Electric rate increases															33.4
Return on common equity															9.75%	9.60%
Common equity ratio															48.00%	48.00%
Scenario, Forecast [Member] | Gas [Member] | CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Return on common equity														9.30%			9.30%
Common equity ratio														48.00%			48.00%
Scenario, Forecast [Member] | Gas [Member] | O&R [Member]
Public Utilities, General Disclosures [Line Items]
Electric rate increases															$40.70
Return on common equity															9.75%
Common equity ratio															48.00%

Regulatory_Matters_Summary_of_2

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Gas) (Detail) (USD $)	12 Months Ended						36 Months Ended	12 Months Ended		36 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2013	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Cost reconciliation, deferred net regulatory assets	$615,000,000	$604,000,000
Cost reconciliations, deferred net regulatory liabilities	910,000,000	871,000,000
CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Cost reconciliation, deferred net regulatory assets	574,000,000	569,000,000
Cost reconciliations, deferred net regulatory liabilities	863,000,000	825,000,000
CECONY [Member] | Gas [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes	-54,600,000		47,000,000		48,000,000	47,000,000
Amortizations to income of net regulatory (assets) and liabilities							-53,100,000
Percentage of revenue reserve	15.00%		25.00%		25.00%	25.00%
Amount of revenues retained	70,000,000	64,000,000		57,000,000
Deferred revenues	28,000,000	36,000,000		22,000,000
Recognize penalties	0
Cost reconciliation, deferred net regulatory assets	38,000,000	26,000,000		9,000,000
Cost reconciliations, deferred net regulatory liabilities	0	9,500,000		2,900,000
Average rate base	3,521,000,000		3,434,000,000		3,245,000,000	3,027,000,000
Authorized return on common equity, austerity measures		2,000,000		4,000,000
Weighted average cost of capital (after-tax)	7.10%		7.46%		7.46%	7.46%
Authorized return on common equity	9.30%		9.60%		9.60%	9.60%
Earnings sharing percentage	9.90%		10.15%		10.15%	10.35%	10.15%
Cost of long-term debt	5.17%		5.57%		5.57%	5.57%	5.57%
Common equity ratio	48.00%		48.00%		48.00%	48.00%
Negative revenue adjustments		0		0
CECONY [Member] | Gas [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes								56,800,000	38,600,000
Amortizations to income of net regulatory (assets) and liabilities										4,000,000
Percentage of revenue reserve								15.00%	15.00%
Average rate base								4,236,000,000	3,863,000,000
Weighted average cost of capital (after-tax)								7.21%	7.13%
Authorized return on common equity								9.30%	9.30%
Earnings sharing percentage								9.90%	9.90%	9.90%
Cost of long-term debt								5.39%	5.23%	5.39%
Common equity ratio								48.00%	48.00%
CECONY [Member] | Gas [Member] | Gas Delivery [Member]
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations	3,899,000,000		3,346,000,000		3,148,000,000	2,934,000,000
CECONY [Member] | Gas [Member] | Gas Delivery [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								4,698,000,000	4,258,000,000
CECONY [Member] | Gas [Member] | Storm Hardening [Member]
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations	3,000,000
CECONY [Member] | Gas [Member] | Storm Hardening [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								30,000,000	8,000,000
CECONY [Member] | Maximum [Member] | Gas [Member]
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained	65,000,000		58,000,000		58,000,000	58,000,000	58,000,000
Potential penalties	33,000,000		12,600,000		12,600,000	12,600,000
CECONY [Member] | Maximum [Member] | Gas [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained								65,000,000	65,000,000	65,000,000
Potential penalties								$56,000,000	$44,000,000

Regulatory_Matters_Summary_of_3

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Gas) (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Other regulatory liabilities	$105
Gas [Member] | CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Potential refund from customers	32
Difference in property taxes	90.00%	80.00%
Maximum impact on return on common equity and deferral of facility relocation expenses	Not more than a 10 basis point
Scenario, Forecast [Member] | Gas [Member] | CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Other regulatory liabilities			$32

Regulatory_Matters_Summary_of_4

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Steam) (Detail) (USD $)	12 Months Ended						36 Months Ended	12 Months Ended		36 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2013	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Cost reconciliation, deferred net regulatory liabilities	$910,000,000	$871,000,000
CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Cost reconciliation, deferred net regulatory liabilities	863,000,000	825,000,000
CECONY [Member] | Steam [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes	-22,400,000		17,800,000		49,500,000	49,500,000
Base rate change through surcharge			31,700,000
Amortizations to income of net regulatory (assets) and liabilities							-20,100,000
Negative revenue adjustments	0	0		0
Cost reconciliation, deferred net regulatory liabilities	42,000,000	17,000,000		12,000,000
Deferred regulatory liability	1,100,000	0		200,000
Average rate base	1,511,000,000		1,613,000,000		1,603,000,000	1,589,000,000
Authorized return on common equity, austerity measures		2,000,000		3,000,000
Earnings sharing, threshold limit	0	500,000
Weighted average cost of capital (after-tax)	7.10%		7.46%		7.46%	7.46%
Cost of long-term debt	5.17%		5.57%		5.57%	5.57%	5.57%
Authorized return on common equity	9.30%		9.60%		9.60%	9.60%
Common equity ratio	48.00%		48.00%		48.00%	48.00%
Earnings sharing percentage	9.90%		10.15%		10.15%	10.35%	10.15%
CECONY [Member] | Steam [Member] | Production [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability	1,752,000,000		433,000,000		426,000,000	415,000,000
CECONY [Member] | Steam [Member] | Distribution [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability	6,000,000		543,000,000		534,000,000	521,000,000
CECONY [Member] | Steam [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes								20,300,000	19,800,000
Amortizations to income of net regulatory (assets) and liabilities										37,000,000
Average rate base								1,604,000,000	1,547,000,000
Weighted average cost of capital (after-tax)								7.21%	7.13%
Cost of long-term debt								5.39%	5.23%	5.39%
Authorized return on common equity								9.30%	9.30%
Common equity ratio								48.00%	48.00%
Earnings sharing percentage								9.90%	9.90%	9.90%
CECONY [Member] | Steam [Member] | Scenario, Forecast [Member] | Production [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability								1,720,000,000	1,732,000,000
CECONY [Member] | Steam [Member] | Scenario, Forecast [Member] | Distribution [Member]
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability								25,000,000	11,000,000
CECONY [Member] | Maximum [Member] | Steam [Member]
Public Utilities, General Disclosures [Line Items]
Potential penalties	1,000,000		1,000,000		1,000,000	1,000,000
CECONY [Member] | Maximum [Member] | Steam [Member] | Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Potential penalties								$1,000,000	$1,000,000

Regulatory_Matters_Summary_of_5

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Steam) (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Other regulatory liabilities	105
Steam [Member] | CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Potential refund from customers			6
Difference in property taxes	90.00%	80.00%
Maximum impact on return on common equity and deferral of facility relocation expenses	Not more than a 10 basis point
Scenario, Forecast [Member] | Steam [Member] | CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Other regulatory liabilities				$8

Regulatory_Matters_Summary_of_6

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Electric) (Detail) (O&R [Member], Electric Transmission [Member], USD $)	12 Months Ended					0 Months Ended	12 Months Ended	36 Months Ended
	Dec. 31, 2014	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2013	Dec. 31, 2012	Nov. 01, 2015	Jun. 30, 2015	Jun. 30, 2015
Public Utilities, General Disclosures [Line Items]
Base rate changes		$8,800,000		$19,400,000
Deferred revenues	-3,400,000		3,200,000		2,600,000
Negative revenue adjustments	0		0		0
Recognition of deferred expenses	-200,000		4,100,000		7,800,000
Deferred regulatory liability	-2,300,000	704,000,000	-1,100,000	678,000,000	4,200,000
Average rate base		708,000,000		671,000,000
Weighted average cost of capital (after-tax)		7.65%		7.61%
Authorized return on common equity		9.50%		9.40%
Earnings sharing, threshold limit	1,000,000
Cost of long-term debt		6.07%		6.07%
Common equity ratio		48.00%		48.00%
Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Potential penalties		3,000,000		3,000,000
Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes							15,200,000
Amortizations to income of net regulatory (assets) and liabilities								-32,200,000
Deferred regulatory liability							753,000,000
Average rate base							759,000,000
Weighted average cost of capital (after-tax)							7.48%
Authorized return on common equity						9.75%	9.60%
Cost of long-term debt							5.64%	5.64%
Common equity ratio						48.00%	48.00%
Scenario, Forecast [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Potential penalties							$3,000,000

Regulatory_Matters_Summary_of_7

Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Gas) (Detail) (USD $)	12 Months Ended						36 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Oct. 31, 2012	Oct. 31, 2011	Oct. 31, 2010	Oct. 31, 2012
Public Utilities, General Disclosures [Line Items]
Cost reconciliations, deferred net regulatory assets	$615,000,000	$604,000,000
O&R [Member] | Gas [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes				4,600,000	9,000,000	9,000,000
Base rate change through surcharge				4,300,000
Amortizations to income of net regulatory (assets) and liabilities							-2,000,000
Deferred revenues	-100,000	700,000	4,700,000
Negative revenue adjustments	0	0	0
Cost reconciliations, deferred net regulatory assets	8,300,000	8,300,000	700,000
Net utility plant reconciliations	0	0	700,000
Average rate base				309,000,000	296,000,000	280,000,000
Weighted average cost of capital (after-tax)				8.49%	8.49%	8.49%
Authorized return on common equity				10.40%	10.40%	10.40%
Earnings sharing percentage				11.40%	11.40%	11.40%	11.40%
Cost of long-term debt				6.81%	6.81%	6.81%	6.81%
Common equity ratio				48.00%	48.00%	48.00%
O&R [Member] | Gas [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Potential penalties				$1,400,000	$1,400,000	$1,400,000

Regulatory_Matters_Summary_of_8

Regulatory Matters - Summary of Utilities Rate Plans (Rockland Electric Company (RECO)) (Detail) (Rockland Electric Company (RECO) [Member], USD $)	12 Months Ended				48 Months Ended	51 Months Ended	12 Months Ended	36 Months Ended	48 Months Ended
	Apr. 30, 2014	Apr. 30, 2013	Apr. 30, 2012	Apr. 30, 2011	Apr. 30, 2014	Jul. 31, 2014	Jul. 31, 2015	Jul. 31, 2015	Jul. 31, 2015
Public Utilities, General Disclosures [Line Items]
Base rate changes				$9.80
Amortizations to income of net regulatory (assets) and liabilities					-3.9	-4.9
Average rate base	148.6	148.6	148.6	148.6
Weighted average cost of capital (after-tax)	8.21%	8.21%	8.21%	8.21%
Authorized return on common equity	10.30%	10.30%	10.30%	10.30%
Cost of long-term debt	6.16%	6.16%	6.16%	6.16%	6.16%
Common equity ratio	50.00%	50.00%	50.00%	50.00%
Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes							13
Amortizations to income of net regulatory (assets) and liabilities								0.4	-25.6
Average rate base							$172.20
Weighted average cost of capital (after-tax)							7.83%
Authorized return on common equity							9.75%
Cost of long-term debt							5.89%	5.89%	5.89%
Common equity ratio							50.00%

Regulatory_Matters_Summary_of_9

Regulatory Matters - Summary of Utilities Rate Plans (Pike County Light & Power Company (Pike)-Electric) (Detail) (Pike County Light & Power Company (Pike) [Member], Electric Transmission [Member], USD $)	12 Months Ended	60 Months Ended	12 Months Ended	60 Months Ended
	Mar. 31, 2010	Mar. 31, 2014	Aug. 31, 2015	Aug. 31, 2015
Public Utilities, General Disclosures [Line Items]
Base rate changes	$900,000
Amortization to income of net regulatory (assets) and liabilities		100,000
Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes			1,250,000
Amortization to income of net regulatory (assets) and liabilities				($70,000)

Recovered_Sheet1

Regulatory Matters - Summary of Utilities Rate Plans (Pike-Gas) (Detail) (Pike County Light & Power Company (Pike) [Member], Gas [Member], USD $)	12 Months Ended
	Mar. 31, 2010	Aug. 31, 2015
Public Utilities, General Disclosures [Line Items]
Base rate changes	$300,000
Scenario, Forecast [Member]
Public Utilities, General Disclosures [Line Items]
Base rate changes		$100,000

Regulatory_Matters_Other_Regul

Regulatory Matters - Other Regulatory Matters - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Public Utilities, General Disclosures [Line Items]
Revenues from electric	$249
Revenues from gas	32
Revenues from steam service	6
Potential refund to customers	1,675
Overcharges of construction expenditures	208
Other regulatory liabilities	105
Regulatory liabilities	187	148
CECONY [Member]
Public Utilities, General Disclosures [Line Items]
Response and restoration costs	503
Capital expenditures	148
Regulatory liabilities	142	107
O&R [Member]
Public Utilities, General Disclosures [Line Items]
Response and restoration costs	91
Capital expenditures	15
Storm Damage [Member]
Public Utilities, General Disclosures [Line Items]
Number of customers interrupted electric distribution service	1,400,000
Net Unbilled Revenue Deferrals [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities	$138	$133
Net Electric Deferrals [Member]
Public Utilities, General Disclosures [Line Items]
Amortization period	10 years

Regulatory_Matters_Regulatory_

Regulatory Matters - Regulatory Assets and Liabilities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Regulatory assets
Regulatory assets - noncurrent	$9,156	$7,201
Regulatory assets - current	148	29
Total Regulatory Assets	9,304	7,230
Regulatory liabilities
Regulatory liabilities - noncurrent	1,993	1,728
Regulatory liabilities - current	187	148
Total Regulatory Liabilities	2,180	1,876
Allowance for Cost of Removal Less Salvage [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	598	540
2014 Rate Plan Rate Base Revenue Deferrals [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	155
Net Unbilled Revenue Deferrals [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	138	133
Prudence Proceeding [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	105	40
Property Tax Refunds [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	87	130
Long-Term Interest Rate Reconciliation [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	78	105
Carrying Charges on Repair Allowance and Bonus Depreciation [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	58	88
New York State Income Tax Rate Change [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	62
World Trade Center Settlement Proceeds [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	41	62
Carrying Charges on Transmission and Distribution Net Plant [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	21	28
Electric Excess Earnings [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	19	22
Other [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	290	208
Refundable Energy Costs - Current [Member]
Regulatory liabilities
Regulatory liabilities - current	128	100
Revenue Decoupling Mechanism [Member]
Regulatory liabilities
Regulatory liabilities - current	30	34
Future Income Tax [Member]
Regulatory liabilities
Regulatory liabilities - current	24
Deferred Derivative Gains - Current [Member]
Regulatory liabilities
Regulatory liabilities - current	5	14
Unrecognized Pension and Other Postretirement Costs [Member]
Regulatory assets
Regulatory assets - noncurrent	4,846	2,730
Future Income Tax [Member]
Regulatory assets
Regulatory assets - noncurrent	2,273	2,145
Environmental Remediation Costs [Member]
Regulatory assets
Regulatory assets - noncurrent	925	938
Deferred Storm Costs [Member]
Regulatory assets
Regulatory assets - noncurrent	319	441
Revenue Taxes [Member]
Regulatory assets
Regulatory assets - noncurrent	219	207
Surcharge for New York State Assessment [Member]
Regulatory assets
Regulatory assets - noncurrent	99	78
Pension and Other Postretirement Benefits Deferrals [Member]
Regulatory assets
Regulatory assets - noncurrent	66	237
Regulatory liabilities
Regulatory liabilities - noncurrent	46	50
Net Electric Deferrals [Member]
Regulatory assets
Regulatory assets - noncurrent	63	83
Unamortized Loss on Reacquired Debt [Member]
Regulatory assets
Regulatory assets - noncurrent	57	65
O & R Property Tax Reconciliation [Member]
Regulatory assets
Regulatory assets - noncurrent	36	22
O&R Transition Bond Charges [Member]
Regulatory assets
Regulatory assets - noncurrent	27	33
Preferred Stock Redemption [Member]
Regulatory assets
Regulatory assets - noncurrent	27	28
Deferred Derivative Losses - Noncurrent [Member]
Regulatory assets
Regulatory assets - noncurrent	25	8
Recoverable Energy Costs - Current [Member]
Regulatory assets
Regulatory assets - noncurrent	19	29
Regulatory assets - current	41	4
Workers' Compensation [Member]
Regulatory assets
Regulatory assets - noncurrent	8	12
Other [Member]
Regulatory assets
Regulatory assets - noncurrent	147	145
Deferred Derivative Losses - Current [Member]
Regulatory assets
Regulatory assets - current	97	25
Future Income Tax - Current [Member]
Regulatory assets
Regulatory assets - current	10
Property Tax Reconciliation [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	295	322
CECONY [Member]
Regulatory assets
Regulatory assets - noncurrent	8,481	6,639
Regulatory assets - current	132	26
Total Regulatory Assets	8,613	6,665
Regulatory liabilities
Regulatory liabilities - noncurrent	1,837	1,598
Regulatory liabilities - current	142	107
Total Regulatory Liabilities	1,979	1,705
CECONY [Member] | Allowance for Cost of Removal Less Salvage [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	499	453
CECONY [Member] | 2014 Rate Plan Rate Base Revenue Deferrals [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	155
CECONY [Member] | Net Unbilled Revenue Deferrals [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	138	133
CECONY [Member] | Prudence Proceeding [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	105	40
CECONY [Member] | Property Tax Refunds [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	87	130
CECONY [Member] | Long-Term Interest Rate Reconciliation [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	78	105
CECONY [Member] | Carrying Charges on Repair Allowance and Bonus Depreciation [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	57	87
CECONY [Member] | New York State Income Tax Rate Change [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	59
CECONY [Member] | World Trade Center Settlement Proceeds [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	41	62
CECONY [Member] | Carrying Charges on Transmission and Distribution Net Plant [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	20	20
CECONY [Member] | Electric Excess Earnings [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	18	18
CECONY [Member] | Other [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	248	178
CECONY [Member] | Refundable Energy Costs - Current [Member]
Regulatory liabilities
Regulatory liabilities - current	84	66
CECONY [Member] | Revenue Decoupling Mechanism [Member]
Regulatory liabilities
Regulatory liabilities - current	30	30
CECONY [Member] | Future Income Tax [Member]
Regulatory liabilities
Regulatory liabilities - current	24
CECONY [Member] | Deferred Derivative Gains - Current [Member]
Regulatory liabilities
Regulatory liabilities - current	4	11
CECONY [Member] | Unrecognized Pension and Other Postretirement Costs [Member]
Regulatory assets
Regulatory assets - noncurrent	4,609	2,610
CECONY [Member] | Future Income Tax [Member]
Regulatory assets
Regulatory assets - noncurrent	2,166	2,030
CECONY [Member] | Environmental Remediation Costs [Member]
Regulatory assets
Regulatory assets - noncurrent	820	830
CECONY [Member] | Deferred Storm Costs [Member]
Regulatory assets
Regulatory assets - noncurrent	224	334
CECONY [Member] | Revenue Taxes [Member]
Regulatory assets
Regulatory assets - noncurrent	208	196
CECONY [Member] | Surcharge for New York State Assessment [Member]
Regulatory assets
Regulatory assets - noncurrent	92	74
CECONY [Member] | Pension and Other Postretirement Benefits Deferrals [Member]
Regulatory assets
Regulatory assets - noncurrent	42	211
Regulatory liabilities
Regulatory liabilities - noncurrent	37	50
CECONY [Member] | Net Electric Deferrals [Member]
Regulatory assets
Regulatory assets - noncurrent	63	83
CECONY [Member] | Unamortized Loss on Reacquired Debt [Member]
Regulatory assets
Regulatory assets - noncurrent	55	62
CECONY [Member] | Preferred Stock Redemption [Member]
Regulatory assets
Regulatory assets - noncurrent	27	28
CECONY [Member] | Deferred Derivative Losses - Noncurrent [Member]
Regulatory assets
Regulatory assets - noncurrent	23	7
CECONY [Member] | Recoverable Energy Costs - Current [Member]
Regulatory assets
Regulatory assets - noncurrent	17	28
Regulatory assets - current	40	4
CECONY [Member] | Workers' Compensation [Member]
Regulatory assets
Regulatory assets - noncurrent	8	12
CECONY [Member] | Other [Member]
Regulatory assets
Regulatory assets - noncurrent	127	134
CECONY [Member] | Deferred Derivative Losses - Current [Member]
Regulatory assets
Regulatory assets - current	92	22
CECONY [Member] | Property Tax Reconciliation [Member]
Regulatory liabilities
Regulatory liabilities - noncurrent	$295	$322

Capitalization_Additional_Info

Capitalization - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		31-May-12
Schedule of Capitalization [Line Items]
Common stock shares, outstanding	21,976,200		21,976,200
Percentage limitation for income available for dividends	100.00%
Rolling average calculation of income available for dividends, years	2 years
Tax-exempt debt issued, value	$494,000,000
Long-term debt, fair value	13,998,000,000		12,082,000,000
Tax-exempt debt	1,130,000,000		1,130,000,000
Long-term debt	12,191,000,000		10,974,000,000
Debt instrument, covenant description	Con Edison's ratio of consolidated debt to consolidated capital to exceed 0.675 to 1
Covenant principal balance amount limit	100,000,000
Level 2 [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	13,362,000,000
Level 3 [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	636,000,000
Maximum [Member]
Schedule of Capitalization [Line Items]
Ratio of consolidated debt to consolidated capital for tax exempt financing	0.675
Transition Bonds, Issued in 2004 [Member]
Schedule of Capitalization [Line Items]
Long-term debt	18,000,000		22,000,000
CECONY [Member]
Schedule of Capitalization [Line Items]
Outstanding shares of Cumulative Preferred Stock					5
Cumulative Preferred Stock, par value					$100
Long-term debt, fair value	12,846,000,000		10,797,000,000
Tax-exempt debt	1,086,000,000	[1]	1,086,000,000	[1]
Long-term debt	11,214,000,000	[1]	9,841,000,000	[1]
CECONY [Member] | Level 2 [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	12,210,000,000
CECONY [Member] | Level 3 [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	636,000,000
Tax-exempt debt	636,000,000
CECONY [Member] | Maximum [Member]
Schedule of Capitalization [Line Items]
Covenant principal balance amount limit	100,000,000
Ratio of consolidated debt to consolidated capital for tax exempt financing	0.65
CECONY [Member] | Minimum [Member]
Schedule of Capitalization [Line Items]
Covenant principal balance amount limit	$150,000,000
[1]	Rates are to be reset weekly or by auction held every 35 days; December 31, 2014 rates shown.

Capitalization_Schedule_of_Lon

Capitalization - Schedule of Long-Term Debt Maturities (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Debt Instrument [Line Items]
2015	$560
2016	731
2017	6
2018	1,260
2019	540
CECONY [Member]
Debt Instrument [Line Items]
2015	350
2016	650
2018	1,200
2019	$475

Capitalization_Carrying_Amount

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Detail) (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument [Line Items]
Carrying Amount	$12,191		$10,974
Fair Value	13,998		12,082
CECONY [Member]
Debt Instrument [Line Items]
Carrying Amount	11,214	[1]	9,841	[1]
Fair Value	$12,846		$10,797
[1]	Rates are to be reset weekly or by auction held every 35 days; December 31, 2014 rates shown.

ShortTerm_Borrowing_Additional

Short-Term Borrowing - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Oct. 31, 2011
Short-term Debt [Line Items]
Credit facility expiry date	31-Oct-17
Commercial paper, outstanding	$800,000,000	$1,451,000,000
Weighted average interest rate	0.40%	0.20%
Letters of credit outstanding under the Credit Agreement	11,000,000	26,000,000
Loans outstanding under credit agreement	0	0
Line of credit facility, covenant terms	Ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2014 this ratio was 0.51 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants.
Ratio of consolidated debt to consolidated total capital	0.51
Minimum percentage of liens on assets	5.00%
October 2016 [Member]
Short-term Debt [Line Items]
Current amount available	1,000,000,000
Maximum [Member]
Short-term Debt [Line Items]
Ratio of consolidated debt to consolidated total capital			0.65
Letters of Credit [Member] | October 2016 [Member]
Short-term Debt [Line Items]
Maximum credit available	2,250,000,000
Maximum borrowing capacity	1,200,000,000
Letters of Credit [Member] | October 2017 [Member]
Short-term Debt [Line Items]
Maximum credit available	2,100,000,000
CECONY [Member]
Short-term Debt [Line Items]
Commercial paper, outstanding	450,000,000	1,210,000,000
Weighted average interest rate	0.40%	0.20%
Letters of credit outstanding under the Credit Agreement	$11,000,000	$11,000,000
Ratio of consolidated debt to consolidated total capital	0.51

Pension_Benefits_Total_Periodi

Pension Benefits - Total Periodic Benefit Costs (Detail) (Pension Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	$227	$267	$237
Interest cost on projected benefit obligation	572	537	547
Expected return on plan assets	-832	-750	-705
Recognition of net actuarial loss	618	832	709
Recognition of prior service costs	4	5	8
NET PERIODIC BENEFIT COST	589	891	796
Amortization of regulatory asset	2	2	2
TOTAL PERIODIC BENEFIT COST	591	893	798
Cost capitalized	-225	-348	-277
Reconciliation to rate level	118	-84	-8
Cost charged to operating expenses	484	461	513
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	211	249	220
Interest cost on projected benefit obligation	536	503	513
Expected return on plan assets	-789	-713	-670
Recognition of net actuarial loss	586	788	670
Recognition of prior service costs	2	4	6
NET PERIODIC BENEFIT COST	546	831	739
Amortization of regulatory asset	2	2	2
TOTAL PERIODIC BENEFIT COST	548	833	741
Cost capitalized	-212	-327	-260
Reconciliation to rate level	108	-87	-12
Cost charged to operating expenses	$444	$419	$469

Pension_Benefits_Total_Periodi1

Pension Benefits - Total Periodic Benefit Costs (Parenthetical) (Detail) (Pension Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase in CECONY's pension obligation	$45

Pension_Benefits_Schedule_of_F

Pension Benefits - Schedule of Funded Status (Detail) (Pension Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CHANGE IN PROJECTED BENEFIT OBLIGATION
Benefit obligation at beginning of year	$12,197	$13,406	$11,825
Service cost - excluding administrative expenses	221	259	224
Interest cost on projected benefit obligation	572	537	547
Net actuarial (gain)/loss	2,641	-1,469	1,323
Plan amendments	6
Benefits paid	-556	-536	-513
BENEFIT OBLIGATION AT END OF YEAR	15,081	12,197	13,406
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	10,755	9,135	7,800
Actual return on plan assets	752	1,310	1,094
Employer contributions	578	879	785
Benefits paid	-556	-536	-513
Administrative expenses	-34	-33	-31
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	11,495	10,755	9,135
FUNDED STATUS	-3,586	-1,442	-4,271
Unrecognized net loss	4,888	2,759	5,594
Unrecognized prior service costs	20	17	23
Accumulated benefit obligation	13,454	11,004	11,911
CECONY [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Benefit obligation at beginning of year	11,429	12,572	11,072
Service cost - excluding administrative expenses	206	241	209
Interest cost on projected benefit obligation	536	503	513
Net actuarial (gain)/loss	2,484	-1,388	1,255
Benefits paid	-518	-499	-477
BENEFIT OBLIGATION AT END OF YEAR	14,137	11,429	12,572
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	10,197	8,668	7,406
Actual return on plan assets	715	1,241	1,040
Employer contributions	535	819	729
Benefits paid	-518	-499	-477
Administrative expenses	-32	-32	-30
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	10,897	10,197	8,668
FUNDED STATUS	-3,240	-1,232	-3,904
Unrecognized net loss	4,616	2,617	5,297
Unrecognized prior service costs	4	6	10
Accumulated benefit obligation	$12,553	$10,268	$11,116

Pension_Benefits_Additional_In

Pension Benefits - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Pension liability	$2,144
Investments value	225	201
Other Nonqualified Supplemental Defined Benefit Pension [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	289	234
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension liability	2,008
Investments value	208	183
CECONY [Member] | Other Nonqualified Supplemental Defined Benefit Pension [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	250	199
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase to regulatory assets	2,101
Charge to OCI	17
Net loss estimated to be amortized	783
Prior service cost estimated to be amortized	4
Accumulated benefit obligation	13,454	11,004	11,911
Assumptions used in calculating net periodic benefit cost	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 Moodybs Investors Service (Moodybs) or Standard & Poorbs) 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, they must have a price between 50 percent and 200 percent of the original price, the yield must lie between 1 percent and 20 percent, 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 planbs projected benefit payments are used to develop a weighted average discount rate.
Estimated future employer contributions	756
Increase in pension benefit obligation	800
Pension Benefits [Member] | CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase to regulatory assets	1,992
Charge to OCI	3
Net loss estimated to be amortized	740
Prior service cost estimated to be amortized	2
Accumulated benefit obligation	12,553	10,268	11,116
Estimated future employer contributions	$703

Pension_Benefits_Schedule_of_A

Pension Benefits - Schedule of Assumptions (Detail) (Pension Benefits [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations	3.90%	4.80%	4.10%
Discount rate, net periodic benefit cost	4.80%	4.10%	4.70%
Expected return on plan assets	8.00%	8.00%	8.00%
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	4.25%	4.35%	4.35%
Rate of compensation increase	4.35%	4.35%	4.35%
O&R [Member]
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	4.00%	4.25%	4.25%
Rate of compensation increase	4.25%	4.25%	4.25%

Pension_Benefits_Schedule_of_E

Pension Benefits - Schedule of Expected Benefit Payments (Detail) (Pension Benefits [Member], USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Defined Benefit Plan Disclosure [Line Items]
2015	$592
2016	615
2017	636
2018	658
2019	678
2020-2024	3,642
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
2015	552
2016	574
2017	594
2018	613
2019	632
2020-2024	$3,388

Pension_Benefits_Schedule_of_P

Pension Benefits - Schedule of Plan Assets Allocations (Detail) (Pension Benefits [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Plan Assets, Total	100.00%	100.00%	100.00%
Scenario, Forecast [Member]
Defined Benefit Plan Disclosure [Line Items]
Equity Securities, Target Allocation, Minimum				55.00%
Equity Securities, Target Allocation, Maximum				65.00%
Debt Securities, Target Allocation, Minimum				27.00%
Debt Securities, Target Allocation, Maximum				33.00%
Real Estate, Target Allocation, Minimum				8.00%
Real Estate, Target Allocation, Maximum				12.00%
Plan Assets, Total				100.00%
Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan Assets	58.00%	60.00%	60.00%
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan Assets	32.00%	30.00%	31.00%
Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan Assets	10.00%	10.00%	9.00%

Pension_Benefits_Schedule_of_F1

Pension Benefits - Schedule of Fair Value of Plan Assets (Detail) (Pension Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Total investments	$12,415	$11,759
Funds for retiree health benefits	-358	-372
Investments (excluding funds for retiree health benefits)	12,057	11,387
Pending activities	-562	-632
Total fair value of plan net assets	11,495	10,755	9,135	7,800
U.S. Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	3,168	3,057
International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	3,202	3,174
Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	114	67
Total fair value of plan net assets	114	67	20
U.S. Government Issued Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	2,113	1,855
Corporate Bonds Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	1,351	1,151
Structured Assets Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	4	4
Other Fixed Income Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	208	150
Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	1,137	1,062
Total fair value of plan net assets	1,137	1,062	833
Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	665	685
Futures [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	229	348
Hedge Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	224	206
Total fair value of plan net assets	224	206
Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	6,389	5,835
Funds for retiree health benefits	-184	-185
Investments (excluding funds for retiree health benefits)	6,205	5,650
Level 1 [Member] | U.S. Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	3,168	3,057
Level 1 [Member] | International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	2,841	2,303
Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	188	127
Level 1 [Member] | Futures [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	192	348
Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	4,551	4,589
Funds for retiree health benefits	-131	-145
Investments (excluding funds for retiree health benefits)	4,420	4,444
Level 2 [Member] | International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	361	871
Level 2 [Member] | U.S. Government Issued Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	2,113	1,855
Level 2 [Member] | Corporate Bonds Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	1,351	1,151
Level 2 [Member] | Structured Assets Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	4	4
Level 2 [Member] | Other Fixed Income Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	208	150
Level 2 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	477	558
Level 2 [Member] | Futures [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	37
Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	1,475	1,335
Funds for retiree health benefits	-43	-42
Investments (excluding funds for retiree health benefits)	1,432	1,293
Level 3 [Member] | Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	114	67
Level 3 [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	1,137	1,062
Level 3 [Member] | Hedge Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	$224	$206

Pension_Benefits_Reconciliatio

Pension Benefits - Reconciliation of Fair Value Balances for Net Assets (Detail) (Pension Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year			$9,135	$7,800
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	11,495	10,755	9,135	7,800
Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	1,062	833
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	86	114
Assets Sold During the Year - Realized Gains/(Losses)	20	1
Purchases Sales and Settlements	-31	114
Transfer In/(Out) of Level 3	0	0
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	1,137	1,062
Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	67	20
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	12	5
Purchases Sales and Settlements	35	42
Transfer In/(Out) of Level 3	0	0
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	114	67
Hedge Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	206
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	11	6
Purchases Sales and Settlements	7	200
Transfer In/(Out) of Level 3	0	0
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	224	206
Investments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	1,335	853
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	109	125
Assets Sold During the Year - Realized Gains/(Losses)	20	1
Purchases Sales and Settlements	11	356
Transfer In/(Out) of Level 3	0	0
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	1,475	1,335
Funds for Retiree Health Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	-42	-31
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	-1	-3
Purchases Sales and Settlements		-8
Transfer In/(Out) of Level 3	0	0
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	-43	-42
Investments (Excluding Funds for Retiree Health Benefits) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	1,293	822
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	108	122
Assets Sold During the Year - Realized Gains/(Losses)	20	1
Purchases Sales and Settlements	11	348
Transfer In/(Out) of Level 3	0	0
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$1,432	$1,293

Pension_Benefits_Schedule_of_E1

Pension Benefits - Schedule of Employer Contribution to Defined Savings Plan (Detail) (Pension Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$32	$30	$23
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$27	$26	$21

Other_Postretirement_Benefits_1

Other Postretirement Benefits - Net Periodic Postretirement Benefit Costs (Detail) (Other Postretirement Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Service cost	$19	$23	$26
Interest cost on accumulated other postretirement benefit obligation	60	54	73
Expected return on plan assets	-77	-77	-85
Recognition of net actuarial loss	57	65	98
Recognition of prior service cost	-19	-27	-21
Recognition of transition obligation			2
NET PERIODIC BENEFIT COST	40	38	93
Cost capitalized	-15	-15	-32
Reconciliation to rate level	10	58	20
Cost charged to operating expenses	35	81	81
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	15	18	21
Interest cost on accumulated other postretirement benefit obligation	52	46	63
Expected return on plan assets	-68	-68	-75
Recognition of net actuarial loss	51	57	87
Recognition of prior service cost	-15	-23	-18
Recognition of transition obligation			2
NET PERIODIC BENEFIT COST	35	30	80
Cost capitalized	-14	-12	-28
Reconciliation to rate level	2	50	16
Cost charged to operating expenses	$23	$68	$68

Other_Postretirement_Benefits_2

Other Postretirement Benefits - Schedule of Funded Status (Detail) (Other Postretirement Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$1,395	$1,454	$1,756
Service cost	19	23	26
Interest cost on accumulated postretirement benefit obligation	60	54	73
Amendments	-12		-127
Net actuarial loss/(gain)	47	-42	-175
Benefits paid and administrative expenses	-134	-136	-146
Participant contributions	36	38	37
Medicare prescription subsidy		4	10
BENEFIT OBLIGATION AT END OF YEAR	1,411	1,395	1,454
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	1,113	1,047	947
Actual return on plan assets	59	153	124
Employer contributions	7	9	83
EGWP payments	12	8
Participant contributions	36	38	37
Benefits paid	-143	-142	-144
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	1,084	1,113	1,047
FUNDED STATUS	-327	-282	-407
Unrecognized net loss	78	70	251
Unrecognized prior service costs	-71	-78	-105
CECONY [Member]
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	1,198	1,238	1,511
Service cost	15	18	21
Interest cost on accumulated postretirement benefit obligation	52	46	63
Amendments			-89
Net actuarial loss/(gain)	28	-20	-178
Benefits paid and administrative expenses	-125	-126	-134
Participant contributions	35	38	36
Medicare prescription subsidy		4	8
BENEFIT OBLIGATION AT END OF YEAR	1,203	1,198	1,238
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	977	922	840
Actual return on plan assets	54	134	109
Employer contributions	7	9	71
EGWP payments	11	7
Participant contributions	35	38	36
Benefits paid	-134	-133	-134
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	950	977	922
FUNDED STATUS	-253	-221	-316
Unrecognized net loss	45	54	197
Unrecognized prior service costs	($46)	($61)	($84)

Other_Postretirement_Benefits_3

Other Postretirement Benefits - Additional Information (Detail) (Other Postretirement Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in postretirement benefit obligations		$102
Reduction to postretirement health benefit obligation recorded as actuarial gain		306
Increase in liability for other postretirement benefits	45
Increase to regulatory assets	14
Charge to OCI	3
Net losses unrecognized to be amortized	33
Prior service cost unrecognized to be amortized	-20
Health care cost trend rate for net periodic benefit cost, current	5.50%
Health care cost trend rate for net periodic benefit cost	4.50%
Year for final trend rate for net periodic benefit cost	2018
Health care cost trend rate for benefit obligations, current	5.25%
Health care cost trend rate for benefit obligations	4.50%
Year for final trend rate for benefit obligations	2018
Expected contributions	6
Maximum [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in postretirement benefit obligations	10
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in postretirement benefit obligations		25
Increase in liability for other postretirement benefits	32
Increase to regulatory assets	6
Charge to OCI	2
Net losses unrecognized to be amortized	29
Prior service cost unrecognized to be amortized	-14
Expected contributions	$6

Other_Postretirement_Benefits_4

Other Postretirement Benefits - Schedule of Actuarial Assumptions (Detail) (Other Postretirement Benefits [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	7.75%	7.75%	8.50%
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations	3.75%	4.50%	3.75%
Discount rate, net periodic benefit cost	4.50%	3.75%	4.55%
O&R [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations	3.85%	4.75%	4.05%
Discount rate, net periodic benefit cost	4.75%	4.05%	4.55%

Other_Postretirement_Benefits_5

Other Postretirement Benefits - Schedule of Change of Assumed Health Care Cost Trend Rate (Detail) (Scenario, Forecast [Member], Other Postretirement Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Effect on accumulated other postretirement benefit obligation, Increase	($21)
Effect on service cost and interest cost components for 2014, Increase	-2
Effect on accumulated other postretirement benefit obligation, Decrease	40
Effect on service cost and interest cost components for 2014, Decrease	1
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Effect on accumulated other postretirement benefit obligation, Increase	-43
Effect on service cost and interest cost components for 2014, Increase	-4
Effect on accumulated other postretirement benefit obligation, Decrease	57
Effect on service cost and interest cost components for 2014, Decrease	$3

Other_Postretirement_Benefits_6

Other Postretirement Benefits - Schedule of Expected Benefit Payments (Detail) (Other Postretirement Benefits [Member], USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Defined Benefit Plan Disclosure [Line Items]
2015 - Benefit Payments	$99
2016 - Benefit Payments	95
2017 - Benefit Payments	94
2018 - Benefit Payments	92
2019 - Benefit Payments	89
2020-2024 - Benefit Payments	419
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
2015 - Benefit Payments	89
2016 - Benefit Payments	85
2017 - Benefit Payments	84
2018 - Benefit Payments	82
2019 - Benefit Payments	79
2020-2024 - Benefit Payments	$364

Other_Postretirement_Benefits_7

Other Postretirement Benefits - Schedule of Plan Assets Allocations (Detail) (CECONY [Member], Other Postretirement Benefits [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Plan Assets	100.00%	100.00%	100.00%
Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan Assets	59.00%	61.00%	62.00%
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan Assets	41.00%	39.00%	38.00%
Scenario, Forecast [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range, Total	100.00%
Scenario, Forecast [Member] | Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Minimum	57.00%
Target Allocation, Maximum	73.00%
Scenario, Forecast [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target Allocation, Minimum	26.00%
Target Allocation, Maximum	44.00%

Other_Postretirement_Benefits_8

Other Postretirement Benefits - Schedule of Fair Values of Plan Assets (Detail) (Other Postretirement Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Total investments	$725	$743
Funds for retiree health benefits	358	372
Investments (including funds for retiree health benefits)	1,083	1,115
Pending activities	1	-2
Total fair value of plan net assets	1,084	1,113	1,047	947
Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	428	450
Other Fixed Income Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	286	286
Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	11	7
Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Funds for retiree health benefits	184	185
Investments (including funds for retiree health benefits)	184	185
Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	725	743
Funds for retiree health benefits	131	145
Investments (including funds for retiree health benefits)	856	888
Level 2 [Member] | Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	428	450
Level 2 [Member] | Other Fixed Income Debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	286	286
Level 2 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	11	7
Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Funds for retiree health benefits	43	42
Investments (including funds for retiree health benefits)	$43	$42

Other_Postretirement_Benefits_9

Other Postretirement Benefits - Reconciliation of Fair Value Balances for Net Assets (Detail) (Other Postretirement Benefits [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year			$1,047	$947
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	1,084	1,113	1,047	947
Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Assets Sold During the Year - Realized Gains/(Losses)	0	0
Transfers (In/Out) of Level 3	0	0
Level 3 [Member] | Funds for Retiree Health Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	42	31
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	1	3
Assets Sold During the Year - Realized Gains/(Losses)	0	0
Purchases Sales and Settlements		8
Transfers (In/Out) of Level 3	0	0
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	43	42
Level 3 [Member] | Investments (including funds for retiree health benefits) [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	42	31
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	1	3
Assets Sold During the Year - Realized Gains/(Losses)	0	0
Purchases Sales and Settlements		8
Transfers (In/Out) of Level 3	0	0
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$43	$42

Environmental_Matters_Accrued_

Environmental Matters - Accrued Liabilities and Regulatory Assets (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Accrued Liabilities:
Accrued Liabilities	$764	$749
Regulatory assets	9,304	7,230
Manufactured Gas Plant Sites [Member]
Accrued Liabilities:
Accrued Liabilities	684	665
Other Superfund Sites [Member]
Accrued Liabilities:
Accrued Liabilities	80	84
Superfund Sites [Member]
Accrued Liabilities:
Accrued Liabilities	764	749
Regulatory assets	925	938
CECONY [Member]
Accrued Liabilities:
Accrued Liabilities	666	644
Regulatory assets	8,613	6,665
CECONY [Member] | Manufactured Gas Plant Sites [Member]
Accrued Liabilities:
Accrued Liabilities	587	562
CECONY [Member] | Other Superfund Sites [Member]
Accrued Liabilities:
Accrued Liabilities	79	82
CECONY [Member] | Superfund Sites [Member]
Accrued Liabilities:
Accrued Liabilities	666	644
Regulatory assets	$820	$830

Environmental_Matters_Addition

Environmental Matters - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Site Contingency [Line Items]
Remediation cost estimate	$29,000,000	$41,000,000
Asbestos Proceedings [Member]
Site Contingency [Line Items]
Estimated undiscounted asbestos liability	8,000,000
Superfund Sites [Member]
Site Contingency [Line Items]
Remediation cost estimate	39,000,000
Superfund Sites [Member] | Manufactured Gas Plant Sites [Member] | Maximum [Member]
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants	2,700,000,000
CECONY [Member]
Site Contingency [Line Items]
Remediation cost estimate	20,000,000	35,000,000
CECONY [Member] | Asbestos Proceedings [Member]
Site Contingency [Line Items]
Estimated undiscounted asbestos liability	7,000,000
Estimated undiscounted asbestos liability in year	15 years
CECONY [Member] | Superfund Sites [Member]
Site Contingency [Line Items]
Remediation cost estimate	35,000,000
CECONY [Member] | Superfund Sites [Member] | Manufactured Gas Plant Sites [Member] | Maximum [Member]
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants	$2,500,000,000

Environmental_Matters_Environm

Environmental Matters - Environmental Remediation Costs (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Environmental Exit Cost [Line Items]
Remediation costs incurred	$29	$41
Insurance recoveries received	7
CECONY [Member]
Environmental Exit Cost [Line Items]
Remediation costs incurred	20	35
Insurance recoveries received	$7

Environmental_Matters_Accrued_1

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Site Contingency [Line Items]
Regulatory assets	$9,304	$7,230
Asbestos Suits [Member]
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers Compensation Insurance [Member]
Site Contingency [Line Items]
Accrued liability	83	87
Regulatory assets	8	12
CECONY [Member]
Site Contingency [Line Items]
Regulatory assets	8,613	6,665
CECONY [Member] | Asbestos Suits [Member]
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY [Member] | Workers Compensation Insurance [Member]
Site Contingency [Line Items]
Accrued liability	78	82
Regulatory assets	$8	$12

Other_Material_Contingencies_A

Other Material Contingencies - Additional Information (Detail) (USD $)	1 Months Ended	12 Months Ended
	Jul. 31, 2007	Dec. 31, 2014	Dec. 31, 2013
	Person	People
		Lawsuits
Guarantor Obligations [Line Items]
Number of person died in steam ruptured	1
Number of suits pending against the company		90
Estimated accrued liability for suits		$50,000,000
Insurance receivable for suits		50,000,000
Description of explosion and fire incident		On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th Street 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 48 people were injured. Additional buildings were also damaged.
Number of people died in explosion and fire incident		8
Number of people injured in explosion and fire incident		48
Guarantee obligations maximum exposure		2,547,000,000	1,331,000,000
Ownership interest, percentage		46.00%
Estimated project cost percentage		175.00%
Manhattan Explosion and Fire [Member]
Guarantor Obligations [Line Items]
Number of suits pending against the company		30
Other [Member]
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure		30,000,000
Electric provider obligation to Public Utility Commission of Texas		5,000,000
Indemnity agreements amount		25,000,000
Con Edison Development [Member]
Guarantor Obligations [Line Items]
Percentage of variable interests		50.00%
Number of guaranteed payments		2
Con Edison Development [Member] | Guarantee One [Member]
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure		63,000,000
Con Edison Development [Member] | Guarantee Two [Member]
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure		31,000,000
Construction and Operation of Solar Energy Facilities [Member]
Guarantor Obligations [Line Items]
Guarantees issued		$3,000,000

Other_Material_Contingencies_T1

Other Material Contingencies - Total Guarantees (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$2,547,000,000	$1,331,000,000
NY Transco [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,361,000,000
Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	901,000,000
Renewable Electric Production Projects [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	255,000,000
Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	30,000,000
0 - 3 years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	2,413,000,000
0 - 3 years [Member] | NY Transco [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,361,000,000
0 - 3 years [Member] | Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	774,000,000
0 - 3 years [Member] | Renewable Electric Production Projects [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	248,000,000
0 - 3 years [Member] | Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	30,000,000
4 - 10 years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	31,000,000
4 - 10 years [Member] | Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	31,000,000
Greater than 10 years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	103,000,000
Greater than 10 years [Member] | Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	96,000,000
Greater than 10 years [Member] | Renewable Electric Production Projects [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$7,000,000

Electricity_Purchase_Agreement2

Electricity Purchase Agreements - Summary of Significant Terms of Electricity Purchase Agreements (Detail) (CECONY [Member])	12 Months Ended
	Dec. 31, 2014
	MW
Brooklyn Navy Yard [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	322
Contracted Output (MW)	291
Contract Start Date	Nov-96
Contract Term (Years)	40 years
Linden Cogeneration [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	1,035
Contracted Output (MW)	607
Contract Start Date	May-92
Contract Term (Years)	25 years
Indeck Corinth [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	147
Contracted Output (MW)	131
Contract Start Date	Jul-95
Contract Term (Years)	20 years
Indian Point [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	2,311
Contracted Output (MW)	500
Contract Start Date	Aug-01
Contract Term (Years)	16 years
Astoria Energy [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	640
Contracted Output (MW)	500
Contract Start Date	May-06
Contract Term (Years)	10 years

Electricity_Purchase_Agreement3

Electricity Purchase Agreements - Summary of Estimated Capacity and Other Fixed Payments (Detail) (CECONY [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Long-term Contract for Purchase of Electric Power [Line Items]
Fixed payment under the contracts	$1,312	$1,282	$1,164
2015 [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Fixed payment under the contracts	252
2016 [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Fixed payment under the contracts	186
2017 [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Fixed payment under the contracts	135
Year 2018 [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Fixed payment under the contracts	62
2019 [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Fixed payment under the contracts	53
All Years Thereafter [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Fixed payment under the contracts	$820

Electricity_Purchase_Agreement4

Electricity Purchase Agreements - Summary of Capacity, Energy and Other Fixed Payments (Detail) (CECONY [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$1,312	$1,282	$1,164
Brooklyn Navy Yard [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	133	118	93
Linden Cogeneration [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	381	346	297
Indeck Corinth [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	80	79	66
Indian Point [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	247	220	204
Astoria Energy [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	230	183	181
Selkirk [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	144	215	196
Independence [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$97	$121	$127

Leases_Schedule_of_Capital_Lea

Leases - Schedule of Capital Leases (Detail) (Common [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Leases
Utility Plant	$3	$3
CECONY [Member]
Leases
Utility Plant	$1	$2

Leases_Additional_Information_

Leases - Additional Information (Detail) (USD $)	1 Months Ended	12 Months Ended
	Jan. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Leased Assets [Line Items]
Accumulated amortization		$1,800,000	$1,000,000
Lease In/Lease Out total investment		259,000,000
Lease In/Lease Out total financed by equity		93,000,000
Lease In/Lease Out total financed by long-term debt		166,000,000
Company's net investment in LILO transactions			0	-76,000,000
Gross investment in leverage leases				228,000,000
Deferred tax liabilities				304,000,000
Estimated charge after-tax			150,000,000
Gain from LILO transaction termination			55,000,000
Decrease in net income		1,000,000	95,000,000
Defray of interest charges relating to potential tax liability	447,000,000
Refund from IRS			10,000,000
Settlement of tax and interest			38,000,000
Transaction One [Member]
Operating Leased Assets [Line Items]
Returned deposit from Internal Revenue Service (IRS)			125,000,000
Transaction Two [Member]
Operating Leased Assets [Line Items]
Returned deposit from Internal Revenue Service (IRS)			48,000,000
CECONY [Member]
Operating Leased Assets [Line Items]
Accumulated amortization		$800,000	$600,000

Leases_Future_Minimum_Lease_Co

Leases - Future Minimum Lease Commitments (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Capital Leased Assets [Line Items]
2015	$1
2016	1
2017	0
2018	0
2019	0
All years thereafter	0
Total	2
Less: amount representing interest	1
Present value of net minimum lease payment	1
CECONY [Member]
Capital Leased Assets [Line Items]
2015	1
2016	1
2017	0
2018	0
2019	0
All years thereafter	0
Total	2
Less: amount representing interest	1
Present value of net minimum lease payment	$1

Leases_Future_Minimum_Rental_P

Leases - Future Minimum Rental Payments for Operating Leases (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Operating Leased Assets [Line Items]
2015	$18
2016	17
2017	16
2018	16
2019	14
All years thereafter	72
Total	153
CECONY [Member]
Operating Leased Assets [Line Items]
2015	14
2016	13
2017	12
2018	12
2019	10
All years thereafter	51
Total	$112

Leases_Schedule_of_Leveraged_L

Leases - Schedule of Leveraged Lease Transactions Effect on Consolidated Income Statement (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Operating Leased Assets [Line Items]
Increase/(decrease) in net income	($1)	($95)
Non Utility Operating Revenue [Member]
Operating Leased Assets [Line Items]
Increase/(decrease) in net income		-27
Interest Expense [Member]
Operating Leased Assets [Line Items]
Increase/(decrease) in net income	13	-131
Income Tax Benefit/(Expense) [Member]
Operating Leased Assets [Line Items]
Increase/(decrease) in net income	($14)	$63

Goodwill_Additional_Informatio

Goodwill - Additional Information (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Goodwill [Line Items]
Goodwill	$429	$429
O&R [Member]
Goodwill [Line Items]
Goodwill	406	406
CECONY [Member]
Goodwill [Line Items]
Goodwill	245	245
O&R [Member]
Goodwill [Line Items]
Goodwill	161	161
Energy Services Acquired [Member]
Goodwill [Line Items]
Goodwill	$23	$23

Income_Tax_Schedule_of_Compone

Income Tax - Schedule of Components of Income Tax (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax [Line Items]
State - Current	$59	$151	$29
State - Deferred	61	-70	97
Federal - Current	-9	285	-13
Federal - Deferred	463	115	493
Amortization of investment tax credits	-6	-5	-6
Total income tax expense	568	476	600
CECONY [Member]
Income Tax [Line Items]
State - Current	66	111	53
State - Deferred	65	-14	53
Federal - Current	158	187	110
Federal - Deferred	271	241	318
Amortization of investment tax credits	-5	-5	-5
Total income tax expense	$555	$520	$529

Income_Tax_Schedule_of_Differe

Income Tax - Schedule of Differences on Deferred Tax Assets and Liabilities (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Income Tax Contingency [Line Items]
Property basis differences	$7,510,000,000	$7,012,000,000
Unrecognized pension and other postretirement costs	1,968,000,000	1,109,000,000
Regulatory asset - future income tax	910,000,000	871,000,000
Environmental remediation costs	376,000,000	381,000,000
Deferred storm costs	129,000,000	179,000,000
Equity investments	168,000,000	21,000,000
Other regulatory assets	347,000,000	402,000,000
Unamortized investment tax credits	126,000,000	43,000,000
Total deferred tax liabilities and investment tax credits	11,534,000,000	10,018,000,000
Accrued pension and other postretirement costs	1,306,000,000	458,000,000
Regulatory liabilities	615,000,000	604,000,000
Superfund and other environmental costs	306,000,000	301,000,000
Asset retirement obligations	77,000,000	58,000,000
Loss carryforwards	21,000,000	12,000,000
Loss carryforwards, valuation reserve	-11,000,000	-12,000,000
Other	272,000,000	253,000,000
Total deferred tax assets	2,586,000,000	1,674,000,000
Net deferred tax liabilities and investment tax credits	8,948,000,000	8,344,000,000
Deferred income taxes and investment tax credits - noncurrent	9,076,000,000	8,466,000,000
Deferred tax assets - current	-128,000,000	-122,000,000
Net deferred tax liabilities and investment tax credits	8,948,000,000	8,344,000,000
CECONY [Member]
Income Tax Contingency [Line Items]
Property basis differences	6,938,000,000	6,424,000,000
Unrecognized pension and other postretirement costs	1,872,000,000	1,060,000,000
Regulatory asset - future income tax	863,000,000	825,000,000
Environmental remediation costs	333,000,000	337,000,000
Deferred storm costs	91,000,000	136,000,000
Other regulatory assets	300,000,000	364,000,000
Unamortized investment tax credits	37,000,000	42,000,000
Total deferred tax liabilities and investment tax credits	10,434,000,000	9,188,000,000
Accrued pension and other postretirement costs	1,155,000,000	364,000,000
Regulatory liabilities	574,000,000	569,000,000
Superfund and other environmental costs	264,000,000	256,000,000
Asset retirement obligations	75,000,000	58,000,000
Other	203,000,000	209,000,000
Total deferred tax assets	2,271,000,000	1,456,000,000
Net deferred tax liabilities and investment tax credits	8,163,000,000	7,732,000,000
Deferred income taxes and investment tax credits - noncurrent	8,257,000,000	7,832,000,000
Deferred tax assets - current	-94,000,000	-100,000,000
Net deferred tax liabilities and investment tax credits	$8,163,000,000	$7,732,000,000

Income_Tax_Schedule_of_Income_

Income Tax - Schedule of Income Tax Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Contingency [Line Items]
Federal	35.00%	35.00%	35.00%
State income tax	5.00%	4.00%	4.00%
Cost of removal	-5.00%	-5.00%	-4.00%
Manufacturing deduction		-1.00%
Other	-1.00%	-2.00%	-1.00%
Effective tax rate	34.00%	31.00%	34.00%
CECONY [Member]
Income Tax Contingency [Line Items]
Federal	35.00%	35.00%	35.00%
State income tax	5.00%	5.00%	4.00%
Cost of removal	-5.00%	-5.00%	-4.00%
Other	-1.00%	-1.00%	-1.00%
Effective tax rate	34.00%	34.00%	34.00%

Income_Tax_Additional_Informat

Income Tax - Additional Information (Detail) (USD $)	1 Months Ended		12 Months Ended		1 Months Ended
	Mar. 31, 2014	Feb. 28, 2014	Dec. 31, 2014	Dec. 31, 2013	Jan. 31, 2015
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward expire date			2019 through 2034
Deferred tax asset, loss carryforward			$21,000,000	$12,000,000
Corporate franchise tax rate	6.50%	7.10%
Decrease in accumulated deferred tax liabilities			74,000,000
Decrease in regulatory asset			11,000,000
Increase in regulatory liability			62,000,000
Expired depreciation bonus percentage				50.00%
Increase in estimated prior year liabilities			27,000,000	253,000,000
Effective income tax rate reconciliation ,uncertainty of taxes			26,000,000
Effective income tax rate reconciliation, uncertainty net of federal taxes			17,000,000
Interest charges related to uncertain tax positions				121,000,000
Reduced interest expenses				10,000,000
Interest charges related to uncertain tax position, LILO transaction				131,000,000
Amount of interest and penalties in their consolidated balance sheets			0	0
Unrecognized tax benefits amount			34,000,000
Unrecognized tax benefits, net of federal taxes			22,000,000
Subsequent Event [Member]
Operating Loss Carryforwards [Line Items]
Income tax refund requested					224,000,000
CECONY [Member]
Operating Loss Carryforwards [Line Items]
Decrease in accumulated deferred tax liabilities			69,000,000
Decrease in regulatory asset			10,000,000
Increase in regulatory liability			59,000,000
Increase in estimated prior year liabilities			2,000,000
Effective income tax rate reconciliation ,uncertainty of taxes			2,000,000
Effective income tax rate reconciliation, uncertainty net of federal taxes			1,000,000
Unrecognized tax benefits amount			2,000,000
Unrecognized tax benefits, net of federal taxes			1,000,000
CECONY [Member] | Subsequent Event [Member]
Operating Loss Carryforwards [Line Items]
Income tax refund requested					128,000,000
New York City [Member]
Operating Loss Carryforwards [Line Items]
Deferred tax asset, valuation allowance			$11,000,000

Income_Tax_Summary_of_Unrecogn

Income Tax - Summary of Unrecognized Tax Benefits (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Contingency [Line Items]
Balance at January 1	$9	$86	$130
Additions based on tax positions related to the current year		5	12
Additions based on tax positions of prior years	27	253
Reductions for tax positions of prior years	-2	-86	-57
Settlements		-249	1
Balance at December 31	34	9	86
CECONY [Member]
Income Tax Contingency [Line Items]
Balance at January 1		74	114
Additions based on tax positions related to the current year			11
Additions based on tax positions of prior years	2
Reductions for tax positions of prior years		-74	-52
Settlements			1
Balance at December 31	$2		$74

StockBased_Compensation_Additi

Stock-Based Compensation - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option awards, LTIP	5,000,000
Stock options vesting period	3 years
Income tax benefit	$12,000,000	$11,000,000	$8,000,000
Number of units issued	37,972
LTIP Weighted Average Price	$55.51
Maximum employer contribution match	1
Amount employee contribution for employer match	9
Maximum employee investment per year	25,000
Maximum percentage allowed to invest	20.00%
Shares purchased on the open market	708,276	864,281	665,718
Weighted average share price per share, on shares purchased on open market	$56.23	$57.24	$59.72
Time Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total expense recognized in future periods	2,000,000
Weighted average period	1 year
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit	10,000,000	10,000,000	7,000,000
CECONY [Member] | Time Based Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total expense recognized in future periods	2,000,000
Weighted average period	1 year
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit	1,000,000	10,000,000
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock options vesting period	3 years
TSR Portion [Member]
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	0.00%
Factor used for adjustment of Performance awards, high end	200.00%
Non-TSR Portion [Member]
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	0.00%
Factor used for adjustment of Performance awards, high end	200.00%
Non-TSR Portion [Member] | Management Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Factor used for adjustment of Performance awards, low end	0.00%
Factor used for adjustment of Performance awards, high end	120.00%
Performance-Based Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock received upon vesting	One share
Compensation expense to be recognized	25,000,000
Weighted average period	1 year
Performance-Based Restricted Stock [Member] | CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$19,000,000
Weighted average period	1 year
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option vesting period	10 years

StockBased_Compensation_StockB

Stock-Based Compensation - Stock-Based Compensation Expense (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$29	$27	$19
Income tax benefit	12	11	8
Performance-Based Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	22	20	14
Time-Based Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	1
Non-Employee Director Deferred Stock Compensation [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	1
Employee Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	3	3	3
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	26	25	18
Income tax benefit	10	10	7
CECONY [Member] | Performance-Based Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	19	18	13
CECONY [Member] | Time-Based Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	1
CECONY [Member] | Non-Employee Director Deferred Stock Compensation [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	1
CECONY [Member] | Employee Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$3	$3	$3

StockBased_Compensation_Summar

Stock-Based Compensation - Summary of Status of Stock Options (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding Shares, Beginning Balance	481,310
Exercised, Shares	-251,460
Forfeited, Shares	0
Outstanding Shares, Ending Balance	229,850
Weighted Average Exercise Price Outstanding, Beginning Balance	$43.38
Weighted Average Exercise Price, Exercised	$43.75
Weighted Average Exercise Price, Forfeited	$0
Weighted Average Exercise Price Outstanding, Ending Balance	$42.99
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding Shares, Beginning Balance	381,010
Exercised, Shares	-189,660
Forfeited, Shares	0
Outstanding Shares, Ending Balance	191,350
Weighted Average Exercise Price Outstanding, Beginning Balance	$43.34
Weighted Average Exercise Price, Exercised	$43.68
Weighted Average Exercise Price, Forfeited	$0
Weighted Average Exercise Price Outstanding, Ending Balance	$43

StockBased_Compensation_Summar1

Stock-Based Compensation - Summary of Status of Stock Options (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Weighted average remaining contractual life	1 year

StockBased_Compensation_Summar2

Stock-Based Compensation - Summary of Stock Options (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Aggregate intrinsic value
Options outstanding	$5	$6
Options exercised	4	2
Cash received by Con Edison for payment of exercise price	11	5
CECONY [Member]
Aggregate intrinsic value
Options outstanding	4	5
Options exercised	3	2
Cash received by Con Edison for payment of exercise price	$8	$4

StockBased_Compensation_Assump

Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Risk-free interest rate, Minimum	0.23%	0.13%	0.15%
Risk-free interest rate, Maximum	3.07%	5.17%	3.39%
Expected term	3 years	3 years	3 years
Expected share price volatility	13.14%	13.52%	15.27%

StockBased_Compensation_Assump1

Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Expected volatility calculation period	3 years

StockBased_Compensation_Summar3

Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Detail) (Performance-Based Restricted Stock [Member], USD $)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested Units, Beginning Balance	1,121,598
Granted, Units	428,310
Vested, Units	-411,704
Forfeited, Units	-37,597
Non-vested Units, Ending Balance	1,100,607
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested Units, Beginning Balance	897,052
Granted, Units	342,001
Vested, Units	-323,483
Forfeited, Units	-35,047
Non-vested Units, Ending Balance	880,523
TSR Portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	49.32
Weighted Average Grant Date Fair Value, Granted	25.34
Weighted Average Grant Date Fair Value, Vested	43.84
Weighted Average Grant Date Fair Value, Forfeited	40.9
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	42.33
TSR Portion [Member] | CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	49.38
Weighted Average Grant Date Fair Value, Granted	25.86
Weighted Average Grant Date Fair Value, Vested	43.93
Weighted Average Grant Date Fair Value, Forfeited	40.84
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	42.58
Non-TSR Portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	55.31
Weighted Average Grant Date Fair Value, Granted	53.65
Weighted Average Grant Date Fair Value, Vested	50.05
Weighted Average Grant Date Fair Value, Forfeited	55.97
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	56.61
Non-TSR Portion [Member] | CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	55.42
Weighted Average Grant Date Fair Value, Granted	53.71
Weighted Average Grant Date Fair Value, Vested	50.08
Weighted Average Grant Date Fair Value, Forfeited	55.95
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	56.7

StockBased_Compensation_Summar4

Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Parenthetical) (Detail) (Performance-Based Restricted Stock [Member])	12 Months Ended
	Dec. 31, 2014
TSR Portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%
Non-TSR Portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%

StockBased_Compensation_Summar5

Stock-Based Compensation - Summary of Changes in Status of Time-Based Awards (Detail) (Time Based Awards [Member], USD $)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested Units, Beginning Balance	66,580
Granted, Units	22,990
Vested, Units	-20,900
Forfeited, Units	-3,247
Non-vested Units, Ending Balance	65,423
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	$56.92
Weighted Average Grant Date Fair Value, Granted	$53.65
Weighted Average Grant Date Fair Value, Vested	$50.74
Weighted Average Grant Date Fair Value, Forfeited	$58.06
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	$57.65
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested Units, Beginning Balance	63,030
Granted, Units	21,790
Vested, Units	-19,800
Forfeited, Units	-2,847
Non-vested Units, Ending Balance	62,173
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	$56.93
Weighted Average Grant Date Fair Value, Granted	$53.65
Weighted Average Grant Date Fair Value, Vested	$50.75
Weighted Average Grant Date Fair Value, Forfeited	$58.27
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	$57.64

Financial_Information_by_Busin2

Financial Information by Business Segment - Financial Data for Business Segments (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Operating revenues	$12,919	$12,354	$12,188
Depreciation and amortization	1,071	1,024	955
Operating income	2,209	2,244	2,339
Interest charges	591	719	604
Income taxes on operating income	589	504	594
Total assets	44,308	40,647	41,209
Construction expenditures	2,721	2,648	2,538
CECONY [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,786	10,430	10,187
Depreciation and amortization	991	946	894
Operating income	2,139	2,060	2,093
Interest charges	537	521	545
Income taxes on operating income	562	531	514
Total assets	39,637	36,258	36,885
Construction expenditures	2,132	2,135	1,909
CECONY [Member] | Electric Transmission [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	781	749	710
Operating income	1,712	1,595	1,693
Interest charges	412	402	423
Income taxes on operating income	425	380	393
Total assets	30,421	27,673	28,339
Construction expenditures	1,500	1,471	1,375
CECONY [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	132	130	120
Operating income	314	362	346
Interest charges	89	83	82
Income taxes on operating income	88	112	99
Total assets	6,530	6,008	5,925
Construction expenditures	549	536	426
CECONY [Member] | Steam [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	78	67	64
Operating income	113	103	54
Interest charges	36	36	40
Income taxes on operating income	49	39	22
Total assets	2,686	2,577	2,621
Construction expenditures	83	128	108
O&R [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	61	56	53
Operating income	128	120	123
Interest charges	35	37	31
Income taxes on operating income	35	20	28
Total assets	2,837	2,545	2,671
Construction expenditures	142	135	137
O&R [Member] | Electric Transmission [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	46	41	38
Operating income	103	87	83
Interest charges	24	25	19
Income taxes on operating income	29	13	17
Total assets	2,042	1,898	1,960
Construction expenditures	105	98	98
O&R [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	15	15	15
Operating income	25	33	40
Interest charges	10	11	10
Income taxes on operating income	6	7	11
Total assets	794	645	706
Construction expenditures	37	37	39
O&R [Member] | Other [Member]
Segment Reporting Information [Line Items]
Interest charges	1	1	2
Total assets	1	2	5
Competitive Energy Businesses [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization	19	23	8
Operating income	-60	63	125
Interest charges	-8	135	1
Income taxes on operating income	-8	-41	52
Total assets	1,026	1,314	1,061
Construction expenditures	447	378	492
Other [Member]
Segment Reporting Information [Line Items]
Depreciation and amortization		-1
Operating income	2	1	-2
Interest charges	27	26	27
Income taxes on operating income		-6
Total assets	808	530	592
Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	12,919	12,354	12,188
Operating Segments [Member] | CECONY [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,786	10,430	10,187
Operating Segments [Member] | CECONY [Member] | Electric Transmission [Member]
Segment Reporting Information [Line Items]
Operating revenues	8,437	8,131	8,176
Operating Segments [Member] | CECONY [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,721	1,616	1,415
Operating Segments [Member] | CECONY [Member] | Steam [Member]
Segment Reporting Information [Line Items]
Operating revenues	628	683	596
Operating Segments [Member] | O&R [Member]
Segment Reporting Information [Line Items]
Operating revenues	892	833	795
Operating Segments [Member] | O&R [Member] | Electric Transmission [Member]
Segment Reporting Information [Line Items]
Operating revenues	680	628	592
Operating Segments [Member] | O&R [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	212	205	203
Operating Segments [Member] | Competitive Energy Businesses [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,244	1,096	1,213
Operating Segments [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	-3	-5	-7
Inter-Segment Revenues [Member] | CECONY [Member]
Segment Reporting Information [Line Items]
Operating revenues	-106	-103	-97
Inter-Segment Revenues [Member] | CECONY [Member] | Electric Transmission [Member]
Segment Reporting Information [Line Items]
Operating revenues	16	16	15
Inter-Segment Revenues [Member] | CECONY [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	6	5	5
Inter-Segment Revenues [Member] | CECONY [Member] | Steam [Member]
Segment Reporting Information [Line Items]
Operating revenues	84	82	77
Inter-Segment Revenues [Member] | Competitive Energy Businesses [Member]
Segment Reporting Information [Line Items]
Operating revenues	-10	5	8
Inter-Segment Revenues [Member] | Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	$10	($5)	($8)

Financial_Information_by_Busin3

Financial Information by Business Segment - Financial Data for Business Segments (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Income taxes on non-operating income	($21)	($28)	$6
CECONY [Member]
Segment Reporting Information [Line Items]
Income taxes on non-operating income	($7)	($11)	$15

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	($163)	$53
Gross Amounts Offset	140	-3
Net Amounts of Assets/(Liabilities)	-23	50
Fair Value of Derivative Assets, Current [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	111	134
Gross Amounts Offset	-67	-77
Net Amounts of Assets/(Liabilities)	44	57
Fair Value of Derivative Assets, Non-current [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	34	32
Gross Amounts Offset	-23	-24
Net Amounts of Assets/(Liabilities)	11	8
Fair Value of Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	145	166
Gross Amounts Offset	-90	-101
Net Amounts of Assets/(Liabilities)	55	65
Fair Value of Derivative Liabilities, Current [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	-242	-82
Gross Amounts Offset	139	72
Net Amounts of Assets/(Liabilities)	-103	-10
Fair Value of Derivative Liabilities, Non-current [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	-66	-31
Gross Amounts Offset	91	26
Net Amounts of Assets/(Liabilities)	25	-5
Fair Value of Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	-308	-113
Gross Amounts Offset	230	98
Net Amounts of Assets/(Liabilities)	-78	-15
CECONY [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	-90	-10
Gross Amounts Offset	45	5
Net Amounts of Assets/(Liabilities)	-45	-5
CECONY [Member] | Fair Value of Derivative Assets, Current [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	26	27
Gross Amounts Offset	-15	-19
Net Amounts of Assets/(Liabilities)	11	8
CECONY [Member] | Fair Value of Derivative Assets, Non-current [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	22	14
Gross Amounts Offset	-20	-13
Net Amounts of Assets/(Liabilities)	2	1
CECONY [Member] | Fair Value of Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	48	41
Gross Amounts Offset	-35	-32
Net Amounts of Assets/(Liabilities)	13	9
CECONY [Member] | Fair Value of Derivative Liabilities, Current [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	-96	-32
Gross Amounts Offset	48	21
Net Amounts of Assets/(Liabilities)	-48	-11
CECONY [Member] | Fair Value of Derivative Liabilities, Non-current [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	-42	-19
Gross Amounts Offset	32	16
Net Amounts of Assets/(Liabilities)	-10	-3
CECONY [Member] | Fair Value of Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	-138	-51
Gross Amounts Offset	80	37
Net Amounts of Assets/(Liabilities)	($58)	($14)

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Parenthetical) (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]
Margin deposits	$27	$17
CECONY [Member]
Derivatives, Fair Value [Line Items]
Margin deposits	$25	$16

Derivative_Instruments_and_Hed4

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	($9)	$14
Total deferred gains/(losses)	-56	35
Net deferred gains/(losses)	-65	49
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	-123	72
Deferred Derivative Gains - Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	-10	14
Deferred Derivative Gains, Long-term [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	1
Deferred Derivative Losses, Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	-75	47
Recoverable Energy Costs - Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	36	-39
Deferred Derivative Losses, Noncurrent [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	-17	27
CECONY [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	-6	11
Total deferred gains/(losses)	-61	14
Net deferred gains/(losses)	-67	25
CECONY [Member] | Deferred Derivative Gains - Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	-7	11
CECONY [Member] | Deferred Derivative Gains, Long-term [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	1
CECONY [Member] | Deferred Derivative Losses, Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	-70	38
CECONY [Member] | Recoverable Energy Costs - Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	26	-37
CECONY [Member] | Deferred Derivative Losses, Noncurrent [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	-17	13
Purchased Power Costs [Member]
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	-37	90
Gas Purchased for Resale [Member]
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	-115	-27
Non-utility Revenue [Member]
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$29	$9

Derivative_Instruments_and_Hed5

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Non Utility Operating Revenue [Member]
Derivatives, Fair Value [Line Items]
Unrealized gain/(loss) on derivatives	$4
Purchased Power Costs [Member]
Derivatives, Fair Value [Line Items]
Unrealized gain/(loss) on derivatives	$132	$74

Derivative_Instruments_and_Hed6

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Detail)	12 Months Ended
	Dec. 31, 2014
	MWh
Electric Energy Derivative [Member]
Derivatives, Fair Value [Line Items]
MWHs	17,792,555
Electric Capacity Derivative [Member]
Derivatives, Fair Value [Line Items]
MWs	7,706
Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Dths	66,793,011
CECONY [Member] | Electric Energy Derivative [Member]
Derivatives, Fair Value [Line Items]
MWHs	5,543,250
CECONY [Member] | Electric Capacity Derivative [Member]
Derivatives, Fair Value [Line Items]
MWs	2,100
CECONY [Member] | Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Dths	62,065,000

Derivative_Instruments_and_Hed7

Derivative Instruments and Hedging Activities - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$148
Makeup of net credit exposure independent system operators	45
Makeup of net credit exposure with commodity exchange brokers	79
Makeup of net credit exposure with investment-grade counterparties	20
Makeup of net credit exposure non-investment grade/non-rated counterparties	4
CECONY [Member]
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$25

Derivative_Instruments_and_Hed8

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]
Aggregate fair value - net liabilities	$78
Collateral posted	1
Downgrade One Level from Current Ratings [Member]
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	6
Downgrade to Below Investment Grade from Current Ratings [Member]
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	105
CECONY [Member]
Derivatives, Fair Value [Line Items]
Aggregate fair value - net liabilities	58
CECONY [Member] | Downgrade One Level from Current Ratings [Member]
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	2
CECONY [Member] | Downgrade to Below Investment Grade from Current Ratings [Member]
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	$63

Derivative_Instruments_and_Hed9

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Parenthetical) (Detail) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]
Collateral posted	$1
Downgrade to Below Investment Grade from Current Ratings [Member]
Derivatives, Fair Value [Line Items]
Derivatives in net asset position additional collateral	15
Additional Collateral Required Due To Loss Of Unsecured Credit [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	16
Additional Collateral Required Due To Loss Of Unsecured Credit [Member] | CECONY [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	$3

Fair_Value_Measurements_Assets

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	$361	$336
Total liabilities	78	17
CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	299	262
Total liabilities	58	14
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	166	144
Total liabilities	18	5
Level 1 [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	156	137
Total liabilities	16	5
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	194	243
Total liabilities	246	86
Level 2 [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	109	116
Total liabilities	91	27
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	28	11
Total liabilities	8	2
Level 3 [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	13	6
Commodity [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	82	82
Derivative liabilities	78	15
Commodity [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	38	25
Derivative liabilities	58	14
Commodity [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3	3
Derivative liabilities	18	5
Commodity [Member] | Level 1 [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	3
Derivative liabilities	16	5
Commodity [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	78	130
Derivative liabilities	246	84
Commodity [Member] | Level 2 [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3	13
Derivative liabilities	91	27
Commodity [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	28	11
Derivative liabilities	8	2
Commodity [Member] | Level 3 [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	13	6
Other [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	279	254
Other [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	261	237
Other [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	163	141
Other [Member] | Level 1 [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	155	134
Other [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	116	113
Other [Member] | Level 2 [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	106	103
Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		2
Interest Rate Contract [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		2
Netting Adjustments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	-27	-62
Total liabilities	-194	-76
Netting Adjustments [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	21	3
Total liabilities	-49	-18
Netting Adjustments [Member] | Commodity [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	-27	-62
Derivative liabilities	-194	-76
Netting Adjustments [Member] | Commodity [Member] | CECONY [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	21	3
Derivative liabilities	($49)	($18)

Fair_Value_Measurements_Assets1

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Parenthetical) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Fair Value Disclosures [Abstract]
Transfers between levels 1,2 and 3	$0	$0

Fair_Value_Measurements_Schedu

Fair Value Measurements - Schedule of Commodity Derivatives (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Electricity [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Natural Gas [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Transmission Congestion Contracts / Financial Transmission Rights [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Minimum [Member] | Discount to Adjust Auction Prices for Inter-Zonal Forward Price Curves [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	9.60%
Minimum [Member] | Discount to Adjust Auction Prices for Historical Monthly Realized Settlements [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	32.30%
Minimum [Member] | Inter-Zonal Forward Price Curves Adjusted for Historical Zonal Losses [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range	-2.66
Minimum [Member] | Forward Energy Prices [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range	22.59
Minimum [Member] | Forward Capacity Prices [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range	1
Minimum [Member] | Forward Gas Prices [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range	-1.64
Maximum [Member] | Discount to Adjust Auction Prices for Inter-Zonal Forward Price Curves [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	57.90%
Maximum [Member] | Discount to Adjust Auction Prices for Historical Monthly Realized Settlements [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	56.10%
Maximum [Member] | Inter-Zonal Forward Price Curves Adjusted for Historical Zonal Losses [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range	16.49
Maximum [Member] | Forward Energy Prices [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range	120
Maximum [Member] | Forward Capacity Prices [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range	8.8
Maximum [Member] | Forward Gas Prices [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range	5
Level 3 [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	20
Level 3 [Member] | Electricity [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	1
Level 3 [Member] | Natural Gas [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	2
Level 3 [Member] | Transmission Congestion Contracts / Financial Transmission Rights [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	17
CECONY [Member] | Transmission Congestion Contracts [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
CECONY [Member] | Minimum [Member] | Discount to Adjust Auction Prices for Inter-Zonal Forward Price Curves [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	9.60%
CECONY [Member] | Minimum [Member] | Discount to Adjust Auction Prices for Historical Monthly Realized Settlements [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	32.30%
CECONY [Member] | Maximum [Member] | Discount to Adjust Auction Prices for Inter-Zonal Forward Price Curves [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	57.90%
CECONY [Member] | Maximum [Member] | Discount to Adjust Auction Prices for Historical Monthly Realized Settlements [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	56.10%
CECONY [Member] | Level 3 [Member] | Transmission Congestion Contracts [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	13

Fair_Value_Measurements_Reconc

Fair Value Measurements - Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	$9	($5)
Included in Earnings	30	7
Included in Regulatory Assets and Liabilities	7	18
Purchases	22	17
Settlements	-48	-28
Ending Balance	20	9
CECONY [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	6	10
Included in Earnings	2	7
Included in Regulatory Assets and Liabilities	7	-1
Purchases	16	13
Settlements	-18	-23
Ending Balance	$13	$6

Fair_Value_Measurements_Additi

Fair Value Measurements - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Non-utility Revenues [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value, assets measured on recurring basis, change in unrealized gain (loss)		($2)
Purchased Power Costs [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value, assets measured on recurring basis, change in unrealized gain (loss)	2	3
Competitive Energy Businesses [Member] | Non-utility Revenues [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative liabilities		-2
Competitive Energy Businesses [Member] | Purchased Power Costs [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative liabilities	$27	$5

Variable_Interest_Entities_Add

Variable Interest Entities - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Variable Interest Entity [Line Items]
Net proceeds on sale	$108
Gain on sale, pretax	45
Non controlling interest of third party	9
Noncontrolling Interest [Member]
Variable Interest Entity [Line Items]
Non controlling interest of third party	9
Variable Interest Entity, Not Primary Beneficiary [Member] | Copper Mountain Solar 3 [Member]
Variable Interest Entity [Line Items]
Percentage of variable interests	50.00%
Variable Interest Entity, Not Primary Beneficiary [Member] | California Solar [Member]
Variable Interest Entity [Line Items]
Percentage of variable interests	50.00%
Variable Interest Entity, Not Primary Beneficiary [Member] | Broken Bow II [Member]
Variable Interest Entity [Line Items]
Percentage of variable interests	50.00%
Variable Interest Entity, Not Primary Beneficiary [Member] | Nevada [Member] | Copper Mountain Solar 3 [Member]
Variable Interest Entity [Line Items]
Generating capacity	250
Variable Interest Entity, Not Primary Beneficiary [Member] | Nebraska [Member] | Broken Bow II [Member]
Variable Interest Entity [Line Items]
Generating capacity	75
Variable Interest Entity, Primary Beneficiary [Member] | Texas Solar 4 [Member]
Variable Interest Entity [Line Items]
Percentage of variable interests	80.00%
Purchase of membership interest, amount	49
Net assets	58
Variable Interest Entity, Primary Beneficiary [Member] | Texas Solar 4 [Member] | Noncontrolling Interest [Member]
Variable Interest Entity [Line Items]
Non controlling interest of third party	9
Variable Interest Entity, Primary Beneficiary [Member] | Texas [Member] | Texas Solar 4 [Member]
Variable Interest Entity [Line Items]
Generating capacity	40
California Solar [Member]
Variable Interest Entity [Line Items]
Percentage of variable interests sold	50.00%
Net proceeds on sale	108
Gain on sale, pretax	45
Gain on sale, net of tax	$26
California Solar [Member] | California [Member]
Variable Interest Entity [Line Items]
Generating capacity	110
CECONY [Member]
Variable Interest Entity [Line Items]
Number of potential VIEs, long-term electricity purchase agreements	3

Variable_Interest_Entities_Sch

Variable Interest Entities - Schedule of Sale and Deconsolidation of a Variable Interest Entity (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Variable Interest Entity [Line Items]
Proceeds from sale, net of transaction costs of $1	$108
Non-utility property, less accumulated depreciation	-388	-605
Long-term debt, including current portion	12,191	10,974
Gain on sale of solar electric production projects	-45
California Solar [Member]
Variable Interest Entity [Line Items]
Proceeds from sale, net of transaction costs of $1	108
Non-utility property, less accumulated depreciation	-341
Other assets, including working capital	-31
Long-term debt, including current portion	217
Other liabilities	9
Gain on sale of solar electric production projects	-45
Equity method investment upon deconsolidation	($83)

Variable_Interest_Entities_Sch1

Variable Interest Entities - Schedule of Sale and Deconsolidation of a Variable Interest Entity (Parenthetical) (Detail) (California Solar [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
California Solar [Member]
Variable Interest Entity [Line Items]
Transaction costs	$1

Variable_Interest_Entities_Sch2

Variable Interest Entities - Schedule of Assets and Liabilities Included in Consolidated Balance Sheet (Detail) (Variable Interest Entity, Primary Beneficiary [Member], Texas Solar 4 [Member], USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Variable Interest Entity [Line Items]
Assets	$135
Liabilities	77
Restricted Cash [Member]
Variable Interest Entity [Line Items]
Assets	13
Non-utility Property, less Accumulated Depreciation [Member]
Variable Interest Entity [Line Items]
Assets	108
Other Assets [Member]
Variable Interest Entity [Line Items]
Assets	14
Long-term Debt Due within One Year [Member]
Variable Interest Entity [Line Items]
Liabilities	66
Other Liabilities [Member]
Variable Interest Entity [Line Items]
Liabilities	$11

Variable_Interest_Entities_Sum

Variable Interest Entities - Summary of VIEs (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014
	MW
Variable Interest Entity, Not Primary Beneficiary [Member] | Pilesgrove [Member] | New Jersey [Member]
Variable Interest Entity [Line Items]
Generating Capacity Owned	9
Year of Initial Investment	2010
Maximum Exposure to Loss (In Millions)	$26,000,000
Variable Interest Entity, Not Primary Beneficiary [Member] | Mesquite Solar 1 [Member] | Arizona [Member]
Variable Interest Entity [Line Items]
Generating Capacity Owned	83
Power Purchase Agreement Term in Years	20 years
Year of Initial Investment	2013
Maximum Exposure to Loss (In Millions)	111,000,000
Variable Interest Entity, Not Primary Beneficiary [Member] | Copper Mountain Solar 2 [Member] | Nevada [Member]
Variable Interest Entity [Line Items]
Generating Capacity Owned	75
Power Purchase Agreement Term in Years	25 years
Year of Initial Investment	2013
Maximum Exposure to Loss (In Millions)	80,000,000
Variable Interest Entity, Not Primary Beneficiary [Member] | Copper Mountain Solar 3 [Member] | Nevada [Member]
Variable Interest Entity [Line Items]
Generating Capacity Owned	128
Power Purchase Agreement Term in Years	20 years
Year of Initial Investment	2014
Maximum Exposure to Loss (In Millions)	175,000,000
Variable Interest Entity, Not Primary Beneficiary [Member] | California Solar [Member] | California [Member]
Variable Interest Entity [Line Items]
Generating Capacity Owned	55
Power Purchase Agreement Term in Years	25 years
Year of Initial Investment	2012
Maximum Exposure to Loss (In Millions)	81,000,000
Variable Interest Entity, Not Primary Beneficiary [Member] | Broken Bow II [Member] | Nebraska [Member]
Variable Interest Entity [Line Items]
Generating Capacity Owned	37
Power Purchase Agreement Term in Years	25 years
Year of Initial Investment	2014
Maximum Exposure to Loss (In Millions)	57,000,000
Variable Interest Entity, Primary Beneficiary [Member] | Texas Solar 4 [Member] | Texas [Member]
Variable Interest Entity [Line Items]
Generating Capacity Owned	32
Power Purchase Agreement Term in Years	25 years
Year of Initial Investment	2014
Maximum Exposure to Loss (In Millions)	$58,000,000

Variable_Interest_Entities_Sum1

Variable Interest Entities - Summary of VIEs (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2014
Variable Interest Entity, Primary Beneficiary [Member] | Texas Solar 4 [Member]
Variable Interest Entity [Line Items]
Percentage of variable interests	80.00%
Variable Interest Entity, Not Primary Beneficiary, Aggregated Disclosure [Member]
Variable Interest Entity [Line Items]
Percentage of variable interests	50.00%
Minimum [Member] | Solar Renewable Energy Credit Hedge [Member] | Pilesgrove [Member]
Variable Interest Entity [Line Items]
Renewable Energy Credit	3 years
Maximum [Member] | Solar Renewable Energy Credit Hedge [Member] | Pilesgrove [Member]
Variable Interest Entity [Line Items]
Renewable Energy Credit	5 years

Asset_Retirement_Obligations_A

Asset Retirement Obligations - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	$188	$143
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	60
Asset retirement obligations, accretion expense	6
Asset retirement obligations, liabilities settled	21
Asset retirement obligations, reductions	16	17
CECONY [Member]
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	185	143
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	57
Asset retirement obligations, accretion expense	6
Asset retirement obligations, liabilities settled	21
Asset retirement obligations, reductions	$16	$17

Related_Party_Transactions_Sum

Related Party Transactions - Summary of Costs of Administrative and Other Services Provided and Received (Detail) (CECONY [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CECONY [Member]
Related Party Transaction [Line Items]
Cost of services provided	$90	$84	$83
Cost of services received	$57	$52	$49

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CECONY [Member]
Related Party Transaction [Line Items]
Sale of natural gas	$80,000,000	$72,000,000	$54,000,000
Funding limit of CECONY to O&R	250,000,000
O&R [Member]
Related Party Transaction [Line Items]
Outstanding loans to O&R	$0	$0

Schedule_I_Condensed_Financial1

Schedule I - Condensed Financial Information - Condensed Statement of Income and Comprehensive Income (Detail) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule Of Condensed Consolidating Statement Of Operation [Line Items]
Interest expense	($591)	($719)	($604)
NET INCOME FOR COMMON STOCK	1,092	1,062	1,138
Comprehensive Income for Common Stock	1,072	1,090	1,143
Net Income Per Common Share - Basic	$3.73	$3.62	$3.88
Net Income Per Common Share - Diluted	$3.71	$3.61	$3.86
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK	$2.52	$2.46	$2.42
Average Number Of Shares Outstanding-Basic	292.9	292.9	292.9
Average Number Of Shares Outstanding-Diluted	294	294.4	294.5
Consolidated Edison Inc [Member]
Schedule Of Condensed Consolidating Statement Of Operation [Line Items]
Equity in earnings of subsidiaries	1,101	1,062	1,154
Other income (deductions), net of taxes	19	29	12
Interest expense	-28	-29	-28
NET INCOME FOR COMMON STOCK	1,092	1,062	1,138
Comprehensive Income for Common Stock	$1,072	$1,090	$1,143
Net Income Per Common Share - Basic	$3.73	$3.62	$3.88
Net Income Per Common Share - Diluted	$3.71	$3.61	$3.86
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK	$2.52	$2.46	$2.42
Average Number Of Shares Outstanding-Basic	292.9	292.9	292.9
Average Number Of Shares Outstanding-Diluted	294	294.4	294.5

Schedule_I_Condensed_Financial2

Schedule I - Condensed Financial Information - Condensed Statement of Cash Flows (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	$1,092	$1,062	$1,138
Common stock dividends	739	721	709
Change in Assets:
Special deposits	312	-257	-13
Income taxes receivable	-224
Other - net	4	34	40
Net Cash Flows from Operating Activities	2,831	2,552	2,599
INVESTING ACTIVITIES
Net Cash Flows Used in Investing Activities	-2,759	-2,659	-2,523
FINANCING ACTIVITIES
Net proceeds of short-term debt	-651	912	539
Retirement of long-term debt	-480	-709	-305
Common stock dividends	739	721	709
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	-47	387	-330
NET CHANGE FOR THE PERIOD	25	280	-254
BALANCE AT BEGINNING OF PERIOD	674	394	648
BALANCE AT END OF PERIOD	699	674	394
Consolidated Edison Inc [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,092	1,062	1,138
Common stock dividends	-739	-721	-709
Equity in earnings of subsidiaries	-1,101	-1,062	-1,154
Change in Assets:
Special deposits	314	-264
Income taxes receivable	-224
Other - net	-199	166	-208
Net Cash Flows from Operating Activities	642	680	503
INVESTING ACTIVITIES
Contributions to subsidiaries	-1		-100
Net Cash Flows Used in Investing Activities	-1		-100
FINANCING ACTIVITIES
Net proceeds of short-term debt	101	58	115
Retirement of long-term debt	-2	-1	-1
Issuance of common shares for stock plans, net of repurchases	-10	-8	-9
Common stock dividends	-739	-721	-709
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	-650	-672	-604
NET CHANGE FOR THE PERIOD	-9	8	-201
BALANCE AT BEGINNING OF PERIOD	12	4	205
BALANCE AT END OF PERIOD	3	12	4
CECONY [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,058	1,020	1,014
Change in Assets:
Other - net	35	-88	-40
Net Cash Flows from Operating Activities	2,430	2,643	2,346
INVESTING ACTIVITIES
Net Cash Flows Used in Investing Activities	-2,304	-2,417	-1,958
FINANCING ACTIVITIES
Net proceeds of short-term debt	-760	789	421
Retirement of long-term debt	-475	-700	-300
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	-114	54	-407
NET CHANGE FOR THE PERIOD	12	280	-19
BALANCE AT BEGINNING OF PERIOD	633	353	372
BALANCE AT END OF PERIOD	645	633	353
CECONY [Member] | Consolidated Edison Inc [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Common stock dividends	712	728	682
FINANCING ACTIVITIES
Common stock dividends	712	728	682
O&R [Member] | Consolidated Edison Inc [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Common stock dividends	40	38	34
FINANCING ACTIVITIES
Common stock dividends	40	38	34
Competitive Energy Businesses [Member] | Consolidated Edison Inc [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Common stock dividends	8	12	11
FINANCING ACTIVITIES
Common stock dividends	$8	$12	$11

Schedule_I_Condensed_Financial3

Schedule I - Condensed Financial Information - Condensed Balance Sheet (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
CURRENT ASSETS
Cash and temporary cash investments	$699	$674	$394	$648
Special deposits	8	327
Accounts receivable - other	1,201	1,251
Income taxes receivable	224
Prepayments	163	136
Other current assets	278	235
TOTAL CURRENT ASSETS	3,854	3,891
Investments in subsidiaries and others	816	461
Goodwill	429	429
Other noncurrent assets	9,811	7,859
TOTAL ASSETS	44,308	40,647	41,209
CURRENT LIABILITIES
Long-term debt due within one year	560	485
Notes payable	800	1,451
Accrued taxes	72	476
Other current liabilities	508	478
TOTAL CURRENT LIABILITIES	3,781	4,730
LONG-TERM DEBT	11,631	10,489
Shareholders' Equity
Common Shareholders' Equity	12,576	12,245
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	44,308	40,647
Consolidated Edison Inc [Member]
CURRENT ASSETS
Cash and temporary cash investments	3	12	4	205
Special deposits	1	315
Accounts receivable - other		185
Income taxes receivable	224
Accounts receivable from affiliated companies	381	950
Prepayments	5	2
Other current assets	4
TOTAL CURRENT ASSETS	618	1,464
Investments in subsidiaries and others	12,277	11,954
Goodwill	406	406
Deferred income tax	18	14
Other noncurrent assets	11	4
TOTAL ASSETS	13,330	13,842
CURRENT LIABILITIES
Long-term debt due within one year	2	2
Notes payable	274	173
Accounts payable to affiliated companies	147	148
Accrued taxes	13	426
Other current liabilities	10	538
TOTAL CURRENT LIABILITIES	446	1,287
Total Liabilities	446	1,287
LONG-TERM DEBT	308	310
Shareholders' Equity
Common stock, including additional paid-in capital	5,023	5,027
Retained earnings	7,553	7,218
Common Shareholders' Equity	12,576	12,245
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	$13,330	$13,842

Schedule_II_Valuation_and_Qual1

Schedule II - Valuation and Qualifying Accounts - Valuation and Qualifying Accounts (Detail) (Allowance For Uncollectible Accounts [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at Beginning of Period	$103	$105	$97
Charged To Costs And Expenses	98	86	96
Charged To Other Accounts	0	0	0
Deductions	95	88	88
Balance At End of Period	106	103	105
CECONY [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at Beginning of Period	95	96	88
Charged To Costs And Expenses	91	82	90
Charged To Other Accounts	0	0	0
Deductions	88	83	82
Balance At End of Period	$98	$95	$96