Consolidated Edison (ED) 10-Q 5 Nov 15 2015 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Oct. 30, 2015
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
Trading Symbol	ED
Entity Registrant Name	CONSOLIDATED EDISON INC
Entity Central Index Key	1,047,862
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		293,192,258
CECONY
Document Information [Line Items]
Entity Registrant Name	CONSOLIDATED EDISON CO OF NEW YORK INC
Entity Central Index Key	23,632
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

Consolidated Income Statement (

Consolidated Income Statement (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
OPERATING REVENUES
Electric	$ 2,762	$ 2,786	$ 6,937	$ 7,158
Gas	237	237	1,293	1,514
Steam	58	46	529	485
Non-utility	386	321	1,088	934
TOTAL OPERATING REVENUES	3,443	3,390	9,847	10,091
OPERATING EXPENSES
Purchased power	860	875	2,404	2,621
Fuel	31	41	216	231
Gas purchased for resale	64	76	415	627
Other operations and maintenance	869	857	2,485	2,483
Depreciation and amortization	285	270	840	796
Taxes, other than income taxes	504	452	1,459	1,419
TOTAL OPERATING EXPENSES	2,613	2,571	7,819	8,177
Gain on sale of solar electric production projects	0	0	0	45
OPERATING INCOME	830	819	2,028	1,959
OTHER INCOME (DEDUCTIONS)
Investment and other income	12	28	31	53
Allowance for equity funds used during construction	1	1	3	4
Other deductions	(4)	(3)	(11)	(12)
TOTAL OTHER INCOME	9	26	23	45
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	839	845	2,051	2,004
INTEREST EXPENSE
Interest on long-term debt	157	145	469	438
Other interest (income)	6	5	19	(1)
Allowance for borrowed funds used during construction	(1)	0	(2)	(2)
NET INTEREST EXPENSE	162	150	486	435
INCOME BEFORE INCOME TAX EXPENSE	677	695	1,565	1,569
INCOME TAX EXPENSE	249	259	548	559
NET INCOME FOR COMMON STOCK	$ 428	$ 436	$ 1,017	$ 1,010
Net income for common stock per common share-basic (dollars per share)	$ 1.46	$ 1.49	$ 3.47	$ 3.45
Net income for common stock per common share-diluted (dollars per share)	1.45	1.48	3.46	3.44
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK (dollars per share)	$ 0.65	$ 0.630	$ 1.95	$ 1.890
AVERAGE NUMBER OF SHARES OUTSTANDING-BASIC (IN MILLIONS) (shares)	292.9	292.9	292.9	292.9
AVERAGE NUMBER OF SHARES OUTSTANDING-DILUTED (IN MILLIONS) (shares)	294.2	294	294.2	294
CECONY
OPERATING REVENUES
Electric	$ 2,558	$ 2,582	$ 6,416	$ 6,635
Gas	213	210	1,177	1,359
Steam	58	46	529	485
TOTAL OPERATING REVENUES	2,829	2,838	8,122	8,479
OPERATING EXPENSES
Purchased power	526	573	1,423	1,707
Fuel	31	42	216	231
Gas purchased for resale	30	36	282	487
Other operations and maintenance	750	748	2,140	2,172
Depreciation and amortization	262	250	773	737
Taxes, other than income taxes	485	433	1,399	1,359
TOTAL OPERATING EXPENSES	2,084	2,082	6,233	6,693
OPERATING INCOME	745	756	1,889	1,786
OTHER INCOME (DEDUCTIONS)
Investment and other income	(1)	12	3	20
Allowance for equity funds used during construction	1	1	3	3
Other deductions	(3)	(3)	(10)	(10)
TOTAL OTHER INCOME	(3)	10	(4)	13
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	742	766	1,885	1,799
INTEREST EXPENSE
Interest on long-term debt	141	130	423	388
Other interest	5	4	14	11
Allowance for borrowed funds used during construction	(1)	0	(2)	(1)
NET INTEREST EXPENSE	145	134	435	398
INCOME BEFORE INCOME TAX EXPENSE	597	632	1,450	1,401
INCOME TAX EXPENSE	222	233	515	496
NET INCOME FOR COMMON STOCK	$ 375	$ 399	$ 935	$ 905

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
NET INCOME	$ 428	$ 436	$ 1,017	$ 1,010
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	1	7	6
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	7	6
COMPREHENSIVE INCOME FOR COMMON STOCK	429	437	1,024	1,016
CECONY
NET INCOME	375	399	935	905
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	0	2	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	0	2	1
COMPREHENSIVE INCOME	$ 376	$ 399	$ 937	$ 906

Consolidated Statement of Cash

Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
OPERATING ACTIVITIES
NET INCOME	$ 1,017	$ 1,010
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	840	796
Deferred income taxes	466	424
Rate case amortization and accruals	(38)	90
Common equity component of allowance for funds used during construction	(3)	(4)
Net derivative gains	(4)	(14)
Pre-tax gain on sale of solar electric production projects	0	(45)
Other non-cash items (net)	73	10
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers, less allowance for uncollectibles	(82)	(35)
Special deposits	5	312
Materials and supplies, including fuel oil and gas in storage	32	19
Other receivables and other current assets	39	(7)
Income taxes receivable	194	0
Prepayments	(568)	(508)
Accounts payable	83	20
Pensions and retiree benefits obligations, net	566	610
Pensions and retiree benefits contributions	(753)	(582)
Accrued taxes	(19)	(428)
Accrued interest	48	(81)
Superfund and environmental remediation costs, net	23	24
Distributions from equity investments related to renewable electric production projects	29	0
Deferred charges, noncurrent assets and other regulatory assets	(17)	(116)
Deferred credits and other regulatory liabilities	220	237
Other current and noncurrent liabilities	48	19
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,199	1,751
INVESTING ACTIVITIES
Utility construction expenditures	(1,838)	(1,663)
Cost of removal less salvage	(156)	(168)
Non-utility construction expenditures	(366)	(152)
Investments in/acquisitions of renewable electric production projects	(286)	(181)
Proceeds from grants related to solar electric production projects	0	36
Proceeds from sale of solar electric production projects	0	108
Restricted cash	(23)	15
Other investing activities	(18)	9
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,687)	(1,996)
FINANCING ACTIVITIES
Net issuance/(payment) of short-term debt	360	(26)
Issuance of long-term debt	238	850
Retirement of long-term debt	(145)	(478)
Debt issuance costs	(2)	(9)
Common stock dividends	(560)	(553)
Issuance of common shares for stock plans, net of repurchases	(9)	(8)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(118)	(224)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(606)	(469)
BALANCE AT BEGINNING OF PERIOD	699	674
BALANCE AT END OF PERIOD	93	205
LESS: HELD FOR SALE	2	0
BALANCE AT BEGINNING OF PERIOD	699
BALANCE AT END OF PERIOD	91	205
Cash paid/(received) during the period for:
Interest	411	382
Income taxes	(7)	635
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	204	107
CECONY
OPERATING ACTIVITIES
NET INCOME	935	905
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	773	737
Deferred income taxes	391	267
Rate case amortization and accruals	(57)	77
Common equity component of allowance for funds used during construction	(3)	(3)
Other non-cash items (net)	13	(11)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers, less allowance for uncollectibles	(51)	(11)
Materials and supplies, including fuel oil and gas in storage	34	26
Other receivables and other current assets	60	(31)
Accounts receivable from affiliated companies	(32)	(233)
Prepayments	(336)	(353)
Accounts payable	23	(47)
Pensions and retiree benefits obligations, net	530	575
Pensions and retiree benefits contributions	(700)	(539)
Accrued taxes	(1)	(7)
Accrued interest	37	1
Superfund and environmental remediation costs, net	21	27
Accrued taxes to affiliated companies	(8)	(181)
Deferred charges, noncurrent assets and other regulatory assets	(49)	(100)
Deferred credits and other regulatory liabilities	222	218
Other current and noncurrent liabilities	0	(11)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,802	1,306
INVESTING ACTIVITIES
Utility construction expenditures	(1,732)	(1,554)
Cost of removal less salvage	(149)	(163)
Restricted cash	(19)	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,900)	(1,717)
FINANCING ACTIVITIES
Net issuance/(payment) of short-term debt	199	(9)
Issuance of long-term debt	0	850
Retirement of long-term debt	0	(475)
Debt issuance costs	(1)	(9)
Dividend to parent	(694)	(534)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(496)	(177)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(594)	(588)
BALANCE AT BEGINNING OF PERIOD	645	633
BALANCE AT END OF PERIOD	51	45
Cash paid/(received) during the period for:
Interest	376	349
Income taxes	143	749
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$ 152	$ 90

Consolidated Balance Sheet (Una

Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
CURRENT ASSETS
Cash and temporary cash investments	$ 91	$ 699
Special deposits	3	8
Accounts receivable - customers, less allowance for uncollectible accounts	1,194	1,201
Other receivables, less allowance for uncollectible accounts	232	133
Income taxes receivable	30	224
Accrued unbilled revenue	387	500
Fuel oil, gas in storage, materials and supplies, at average cost	338	372
Prepayments	731	163
Regulatory assets	67	148
Deferred tax assets	60	128
Assets held for sale	194	0
Other current assets	178	278
TOTAL CURRENT ASSETS	3,505	3,854
INVESTMENTS	874	816
UTILITY PLANT, AT ORIGINAL COST
General	2,546	2,465
TOTAL	37,310	35,909
Less: Accumulated depreciation	7,940	7,614
Net	29,370	28,295
Construction work in progress	1,106	1,031
NET UTILITY PLANT	30,476	29,326
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	572	388
Construction work in progress	425	113
NET PLANT	31,473	29,827
OTHER NONCURRENT ASSETS
Goodwill	429	429
Intangible assets, less accumulated amortization of $4 in 2015 and 2014	3	3
Regulatory assets	8,445	9,156
Other deferred charges and noncurrent assets	242	223
TOTAL OTHER NONCURRENT ASSETS	9,119	9,811
TOTAL ASSETS	44,971	44,308
CURRENT LIABILITIES
Long-term debt due within one year	761	560
Notes payable	1,160	800
Accounts payable	1,092	1,035
Customer deposits	351	344
Accrued taxes	53	72
Accrued interest	180	132
Accrued wages	96	95
Fair value of derivative liabilities	26	64
Regulatory liabilities	165	187
Liabilities held for sale	82	0
Other current liabilities	463	492
TOTAL CURRENT LIABILITIES	4,429	3,781
NONCURRENT LIABILITIES
Provision for injuries and damages	185	182
Pensions and retiree benefits	3,068	3,914
Superfund and other environmental costs	746	764
Asset retirement obligations	198	188
Fair value of derivative liabilities	17	13
Deferred income taxes and investment tax credits	9,598	9,076
Regulatory liabilities	1,940	1,993
Other deferred credits and noncurrent liabilities	220	181
TOTAL NONCURRENT LIABILITIES	15,972	16,311
LONG-TERM DEBT	11,521	11,631
EQUITY
Common shareholders’ equity	13,040	12,576
Noncontrolling interest	9	9
TOTAL EQUITY (See Statement of Equity)	13,049	12,585
TOTAL LIABILITIES AND EQUITY	44,971	44,308
CECONY
CURRENT ASSETS
Cash and temporary cash investments	51	645
Special deposits	2	2
Accounts receivable - customers, less allowance for uncollectible accounts	1,115	1,064
Other receivables, less allowance for uncollectible accounts	66	71
Accrued unbilled revenue	356	384
Accounts receivable from affiliated companies	164	132
Fuel oil, gas in storage, materials and supplies, at average cost	278	312
Prepayments	462	126
Regulatory assets	53	132
Deferred tax assets	35	94
Other current assets	111	158
TOTAL CURRENT ASSETS	2,693	3,120
INVESTMENTS	281	271
UTILITY PLANT, AT ORIGINAL COST
General	2,337	2,265
TOTAL	34,932	33,584
Less: Accumulated depreciation	7,269	6,970
Net	27,663	26,614
Construction work in progress	1,033	971
NET UTILITY PLANT	28,696	27,585
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	5	5
NET PLANT	28,701	27,590
OTHER NONCURRENT ASSETS
Regulatory assets	7,820	8,481
Other deferred charges and noncurrent assets	175	175
TOTAL OTHER NONCURRENT ASSETS	7,995	8,656
TOTAL ASSETS	39,670	39,637
CURRENT LIABILITIES
Long-term debt due within one year	750	350
Notes payable	649	450
Accounts payable	783	802
Accounts payable to affiliated companies	28	23
Customer deposits	337	330
Accrued taxes	45	46
Accrued taxes to affiliated companies	2	10
Accrued interest	154	117
Accrued wages	87	84
Fair value of derivative liabilities	19	48
Regulatory liabilities	135	142
Other current liabilities	398	415
TOTAL CURRENT LIABILITIES	3,387	2,817
NONCURRENT LIABILITIES
Provision for injuries and damages	179	176
Pensions and retiree benefits	2,708	3,493
Superfund and other environmental costs	651	666
Asset retirement obligations	191	185
Fair value of derivative liabilities	14	10
Deferred income taxes and investment tax credits	8,714	8,257
Regulatory liabilities	1,755	1,837
Other deferred credits and noncurrent liabilities	176	144
TOTAL NONCURRENT LIABILITIES	14,388	14,768
LONG-TERM DEBT	10,465	10,864
EQUITY
Common shareholders’ equity	11,430	11,188
TOTAL LIABILITIES AND EQUITY	39,670	39,637
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	25,998	25,091
Electric | CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	24,485	23,599
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	6,466	6,102
Gas | CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	5,810	5,469
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,300	2,251
Steam | CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,300	$ 2,251

Consolidated Balance Sheet (Un6

Consolidated Balance Sheet (Unaudited) (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Accounts receivable - customers, allowance for uncollectible accounts	$ 88	$ 96
Other receivables, allowance for uncollectible accounts	11	10
Non-utility property, accumulated depreciation	90	91
Intangible assets, accumulated amortization	4	4
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	83	90
Other receivables, allowance for uncollectible accounts	8	8
Non-utility property, accumulated depreciation	$ 25	$ 25

Consolidated Statement of Equit

Consolidated Statement of Equity/Shareholder's Equity (Unaudited) - USD ($) $ in Millions	Total	CECONY	Common Stock	Common StockCECONY	Additional Paid-In Capital	Additional Paid-In CapitalCECONY	Retained Earnings	Retained EarningsCECONY	Repurchased Con Edison StockCECONY	Treasury Stock	Capital Stock Expense	Capital Stock ExpenseCECONY	Accumulated Other Comprehensive Income/(Loss)	Accumulated Other Comprehensive Income/(Loss)CECONY	Noncontrolling Interest
Beginning Balance at Dec. 31, 2013	$ 12,245		$ 32		$ 4,995		$ 8,338			$ (1,034)	$ (61)		$ (25)
Beginning Balance at Dec. 31, 2013		$ 10,847		$ 589		$ 4,234		$ 7,053	$ (962)			$ (61)		$ (6)
Beginning Balance (in shares) at Dec. 31, 2013			292,872,396	235,488,094						23,210,200
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income for common stock	361						361
Net income		334						334
Common stock dividends	(184)	(178)					(184)	(178)
Issuance of common shares for stock plans, net of repurchases					(2)					$ 2
Issuance of common shares for stock plans, net of repurchases (in shares)			51,656							(51,656)
Other comprehensive income	4	1											4	1
Ending Balance at Mar. 31, 2014		11,004		$ 589		4,234		7,209	(962)			(61)		(5)
Ending Balance at Mar. 31, 2014	12,426		$ 32		4,993		8,515			$ (1,032)	(61)		(21)
Ending Balance (in shares) at Mar. 31, 2014			292,924,052	235,488,094						23,158,544
Beginning Balance at Dec. 31, 2013	12,245		$ 32		4,995		8,338			$ (1,034)	(61)		(25)
Beginning Balance at Dec. 31, 2013		10,847		$ 589		4,234		7,053	(962)			(61)		(6)
Beginning Balance (in shares) at Dec. 31, 2013			292,872,396	235,488,094						23,210,200
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income for common stock	1,010	905
Net income	1,010	905
Ending Balance at Sep. 30, 2014		11,219		$ 589		4,234		7,424	(962)			(61)		(5)
Ending Balance at Sep. 30, 2014	12,716		$ 32		4,993		8,794			$ (1,032)	(61)		(19)		$ 9
Ending Balance (in shares) at Sep. 30, 2014			292,871,968	235,488,094						23,210,628
Beginning Balance at Mar. 31, 2014	12,426		$ 32		4,993		8,515			$ (1,032)	(61)		(21)
Beginning Balance at Mar. 31, 2014		11,004		$ 589		4,234		7,209	(962)			(61)		(5)
Beginning Balance (in shares) at Mar. 31, 2014			292,924,052	235,488,094						23,158,544
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income for common stock	212						212
Net income		172						172
Common stock dividends	(184)	(178)					(184)	(178)
Issuance of common shares for stock plans, net of repurchases					0					$ 0
Issuance of common shares for stock plans, net of repurchases (in shares)			(45,658)							45,658
Other comprehensive income	1	0											1	0
Ending Balance at Jun. 30, 2014		10,998		$ 589		4,234		7,203	(962)			(61)
Ending Balance at Jun. 30, 2014	12,455		$ 32		4,993		8,543			$ (1,032)	(61)		(20)
Ending Balance (in shares) at Jun. 30, 2014			292,878,394	235,488,094						23,204,202
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income for common stock	436	399					436
Net income	436	399						399
Common stock dividends	(185)	(178)					(185)	(178)
Issuance of common shares for stock plans, net of repurchases					0					$ 0
Issuance of common shares for stock plans, net of repurchases (in shares)			(6,426)							6,426
Other comprehensive income	1	0											1	0
Ending Balance at Sep. 30, 2014		11,219		$ 589		4,234		7,424	(962)			(61)		(5)
Ending Balance at Sep. 30, 2014	12,716		$ 32		4,993		8,794			$ (1,032)	(61)		(19)		9
Ending Balance (in shares) at Sep. 30, 2014			292,871,968	235,488,094						23,210,628
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interest	9														9
Noncontrolling interest	9
Beginning Balance at Dec. 31, 2014	12,585		$ 32		4,991		8,691			$ (1,032)	(61)		(45)		9
Beginning Balance at Dec. 31, 2014	12,576	11,188		$ 589		4,234		7,399	(962)			(61)		(11)
Beginning Balance (in shares) at Dec. 31, 2014			292,876,196	235,488,094						23,206,400
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income for common stock	370						370
Net income		348						348
Common stock dividends	(190)	(338)					(190)	(338)
Issuance of common shares for stock plans, net of repurchases					2					$ (2)
Issuance of common shares for stock plans, net of repurchases (in shares)			24,600							(24,600)
Other comprehensive income	5	0											5	0
Ending Balance at Mar. 31, 2015		11,198		$ 589		4,234		7,409	(962)			(61)
Ending Balance at Mar. 31, 2015	12,770		$ 32		4,993		8,871			$ (1,034)	(61)		(40)		9
Ending Balance (in shares) at Mar. 31, 2015			292,900,796	235,488,094						23,181,800
Beginning Balance at Dec. 31, 2014	12,585		$ 32		4,991		8,691			$ (1,032)	(61)		(45)		9
Beginning Balance at Dec. 31, 2014	12,576	11,188		$ 589		4,234		7,399	(962)			(61)		(11)
Beginning Balance (in shares) at Dec. 31, 2014			292,876,196	235,488,094						23,206,400
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income for common stock	1,017	935
Net income	1,017	935
Ending Balance at Sep. 30, 2015	13,040	11,430		$ 589		4,234		7,639	(962)			(61)		(9)
Ending Balance at Sep. 30, 2015	13,049		$ 32		5,008		9,137			$ (1,038)	(61)		(38)		9
Ending Balance (in shares) at Sep. 30, 2015			293,084,114	235,488,094						23,210,700
Beginning Balance at Mar. 31, 2015	12,770		$ 32		4,993		8,871			$ (1,034)	(61)		(40)		9
Beginning Balance at Mar. 31, 2015		11,198		$ 589		4,234		7,409	(962)			(61)
Beginning Balance (in shares) at Mar. 31, 2015			292,900,796	235,488,094						23,181,800
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income for common stock	219						219
Net income		211						211
Common stock dividends	(190)	(178)					(190)	(178)
Issuance of common shares for stock plans, net of repurchases	(3)				0					$ (3)
Issuance of common shares for stock plans, net of repurchases (in shares)			(28,134)							28,134
Other comprehensive income	1	1											1	1
Ending Balance at Jun. 30, 2015		11,232		$ 589		4,234		7,442	(962)			(61)		(10)
Ending Balance at Jun. 30, 2015	12,797		$ 32		4,993		8,900			$ (1,037)	(61)		(39)		9
Ending Balance (in shares) at Jun. 30, 2015			292,872,662	235,488,094						23,209,934
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income for common stock	428	375					428
Net income	428	375						375
Common stock dividends	(191)	(178)					(191)	(178)
Issuance of common shares for stock plans, net of repurchases	14				15					$ (1)
Issuance of common shares for stock plans, net of repurchases (in shares)			211,452							766
Other comprehensive income	1	1											1	1
Ending Balance at Sep. 30, 2015	13,040	$ 11,430		$ 589		$ 4,234		$ 7,639	$ (962)			$ (61)		$ (9)
Ending Balance at Sep. 30, 2015	13,049		$ 32		$ 5,008		$ 9,137			$ (1,038)	$ (61)		$ (38)		$ 9
Ending Balance (in shares) at Sep. 30, 2015			293,084,114	235,488,094						23,210,700
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Noncontrolling interest	$ 9

General

General	9 Months Ended
	Sep. 30, 2015
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. The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies’ separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2014 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2015 and June 30, 2015. Certain prior period amounts have been reclassified to conform to the current period presentation. 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 (see Note O) 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 (see Note O), 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
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. The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies’ separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2014 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2015 and June 30, 2015. Certain prior period amounts have been reclassified to conform to the current period presentation. 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 (see Note O) 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 (see Note O), 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 Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2015
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Earnings Per Common Share For the three and nine months ended September 30, 2015 and 2014 , basic and diluted earnings per share (EPS) for Con Edison are calculated as follows: For the Three Months Ended September 30, For the Nine Months Ended September 30, (Millions of Dollars, except per share amounts/Shares in Millions) 2015 2014 2015 2014 Net income for common stock $428 $436 $1,017 $1,010 Weighted average common shares outstanding – basic 292.9 292.9 292.9 292.9 Add: Incremental shares attributable to effect of potentially dilutive securities 1.3 1.1 1.3 1.1 Adjusted weighted average common shares outstanding – diluted 294.2 294.0 294.2 294.0 Net Income for common stock per common share – basic $1.46 $1.49 $3.47 $3.45 Net Income for common stock per common share – diluted $1.45 $1.48 $3.46 $3.44 The computation of diluted EPS for the three and nine months ended September 30, 2014 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect. Changes in Accumulated Other Comprehensive Income/(Loss) by Component For the three and nine months ended September 30, 2015 and 2014 , changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance, accumulated OCI, net of taxes (a) $(39) $(20) $(10) $(5) Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2015 and 2014 (a)(b) 1 1 1 — Current period OCI, net of taxes 1 1 1 — Ending balance, accumulated OCI, net of taxes $(38) $(19) $(9) $(5) For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance, accumulated OCI, net of taxes (a) $(45) $(25) $(11) $(6) OCI before reclassifications, net of tax of $(2) and $(1) for Con Edison in 2015 and 2014, respectively 3 2 — — Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(3) for Con Edison in 2015 and 2014 (a)(b) 4 4 2 1 Current period OCI, net of taxes 7 6 2 1 Ending balance, accumulated OCI, net of taxes $(38) $(19) $(9) $(5) (a) Tax reclassified from accumulated OCI is reported in the income tax expense line item of the income statement. (b) 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 total periodic pension and other postretirement benefit cost. See Notes E and F.
CECONY
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Earnings Per Common Share For the three and nine months ended September 30, 2015 and 2014 , basic and diluted earnings per share (EPS) for Con Edison are calculated as follows: For the Three Months Ended September 30, For the Nine Months Ended September 30, (Millions of Dollars, except per share amounts/Shares in Millions) 2015 2014 2015 2014 Net income for common stock $428 $436 $1,017 $1,010 Weighted average common shares outstanding – basic 292.9 292.9 292.9 292.9 Add: Incremental shares attributable to effect of potentially dilutive securities 1.3 1.1 1.3 1.1 Adjusted weighted average common shares outstanding – diluted 294.2 294.0 294.2 294.0 Net Income for common stock per common share – basic $1.46 $1.49 $3.47 $3.45 Net Income for common stock per common share – diluted $1.45 $1.48 $3.46 $3.44 The computation of diluted EPS for the three and nine months ended September 30, 2014 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect. Changes in Accumulated Other Comprehensive Income/(Loss) by Component For the three and nine months ended September 30, 2015 and 2014 , changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance, accumulated OCI, net of taxes (a) $(39) $(20) $(10) $(5) Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2015 and 2014 (a)(b) 1 1 1 — Current period OCI, net of taxes 1 1 1 — Ending balance, accumulated OCI, net of taxes $(38) $(19) $(9) $(5) For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance, accumulated OCI, net of taxes (a) $(45) $(25) $(11) $(6) OCI before reclassifications, net of tax of $(2) and $(1) for Con Edison in 2015 and 2014, respectively 3 2 — — Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(3) for Con Edison in 2015 and 2014 (a)(b) 4 4 2 1 Current period OCI, net of taxes 7 6 2 1 Ending balance, accumulated OCI, net of taxes $(38) $(19) $(9) $(5) (a) Tax reclassified from accumulated OCI is reported in the income tax expense line item of the income statement. (b) 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 total periodic pension and other postretirement benefit cost. See Notes E and F.

Regulatory Matters

Regulatory Matters	9 Months Ended
	Sep. 30, 2015
Public Utilities, General Disclosures [Line Items]
Regulatory Matters	Regulatory Matters Rate Plans CECONY — Electric In June 2015, the New York State Public Service Commission (NYSPSC) approved an April 2015 Joint Proposal entered into by CECONY, the staff of the NYSPSC and other parties. Under the Joint Proposal, the rate plan for 2016 does not include a rate increase or decrease. The rate plan for 2016 includes additional revenues from the amortization to income of net regulatory liabilities. The following table contains a summary of the rate plan for 2016: Effective period January 2016 – December 2016 Base rate changes None (a) Amortizations to income of net regulatory (assets) and liabilities Additional $123 million of net regulatory liabilities (b). Other revenue sources Continued retention of $90 million of annual transmission congestion revenues. Revenue decoupling mechanism Continued reconciliation of actual electric delivery revenues to those authorized in the rate plan. Recoverable energy costs Continued current rate recovery of purchased power and fuel costs (c). Negative revenue adjustments Continued potential penalties (up to $400 million annually) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support, the impact of new laws and environmental remediation to amounts reflected in rates (d). Net utility plant reconciliations Target levels reflected in rates are as follows: Average rate base $18,282 million Weighted average cost of capital (after-tax) 6.91 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. Cost of long-term debt 5.09 percent Common equity ratio 48 percent (a) The impact of 2014 and 2015 base rate changes under the current electric rate plan will continue to be deferred. $249 million of annual revenues collected from electric customers will continue to be subject to potential refund following NYSPSC staff review of certain costs. Revenues will continue to include $21 million as funding for major storm reserve. (b) Annual amortization of $107 million of the regulatory asset for deferred Superstorm Sandy and other major storm costs will continue. The costs recoverable from customers will be reduced by $4 million . The costs will no longer be subject to NYSPSC staff review and the recovery of the costs will no longer be subject to refund. (c) For transmission service provided pursuant to the open access transmission tariff of PJM Interconnection LLC (PJM), 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 the Federal Energy Regulatory Commission (FERC) a request that would substantially increase the charges for the transmission service. FERC has granted the request and rejected CECONY’s protests. CECONY is challenging the FERC’s decision. In August 2015, PJM submitted a request to FERC that, if approved by FERC, would further increase the charges. In September 2015, CECONY filed a protest to this increase. (d) Deferrals for property taxes will continue to be limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity. In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral of 30 percent of the amount reflected in rates. O&R New York – Electric and Gas In October 2015, the NYSPSC approved a June 2015 Joint Proposal entered into by O&R, the NYSPSC staff and other parties for new electric and gas rate plans. Under the Joint Proposal, the new rate plans are effective November 2015. The following tables contain a summary of the new rate plans: O&R New York - Electric Effective period November 2015 - October 2017 Base rate changes Yr. 1 - $9.3 million Amortizations to income of net regulatory (assets) and liabilities (a) Yr. 1 - $(8.5) million Revenue decoupling mechanism Continued reconciliation of actual electric delivery revenues to those authorized in the rate plan. Recoverable energy costs Continued current rate recovery of purchased power costs. Negative revenue adjustments Potential penalties (up to $4 million annually) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, major storms, property taxes, the impact of new laws and environmental remediation to amounts reflected in rates. Net utility plant reconciliations (b) Target levels reflected in rates are: Average rate base Yr. 1 - $763 million Weighted average cost of capital (after-tax) Yr. 1 - 7.10 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. Cost of long-term debt Yr. 1 - 5.42 percent Common equity ratio 48 percent (a) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a five-year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015. (b) Excludes electric advanced metering infrastructure as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2. O&R New York - Gas Effective period November 2015 - October 2018 Base rate changes Yr. 1 - $16.4 million Amortizations to income of net regulatory (assets) and liabilities (a) Yr. 1 - $(1.7) million Revenue decoupling mechanism Continued reconciliation of actual gas delivery revenues to those authorized in the rate plan, including through weather normalization clause. Recoverable energy costs Continued current rate recovery of purchased gas costs. Negative revenue adjustments Potential penalties (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $5.8 million in Yr. 3) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, property taxes, the impact of new laws and environmental remediation to amounts reflected in rates. Net utility plant reconciliations (b) Target levels reflected in rates are: Average rate base Yr. 1 - $366 million Weighted average cost of capital (after-tax) Yr. 1 - 7.10 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. Cost of long-term debt Yr. 1 - 5.42 percent Common equity ratio 48 percent (a) Reflects that the company will not recover from customers a total of approximately $14 million of regulatory assets for property tax and interest rate reconciliations. Amounts that will not be recovered from customers were charged-off in June 2015. (b) Excludes gas advanced metering infrastructure as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $0.5 million in year 1, $4.2 million in year 2 and $7.2 million in year 3. 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 September 30, 2015 , the company had collected an estimated $1,889 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 disputed 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. In September 2015, the company, the NYSPSC staff and others entered into a Joint Proposal to settle this proceeding and related matters. The Joint Proposal is subject to NYSPSC approval. Pursuant to the Joint Proposal, the company is required to credit $116 million to customers and, for the period 2017 through 2044, to not seek to recover from customers an aggregate $55 million relating to return on its capital expenditures. In addition, the company’s revenues that were made subject to potential refund in this proceeding would no longer be subject to refund. At September 30, 2015, the company had a $100 million regulatory liability for the remaining amount to be credited to customers related to this matter. 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 September 30, 2015 , CECONY and O&R incurred response and restoration costs for Superstorm Sandy of $509 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. Collection from customers of these costs is provided for under the Utilities' current electric rate plans. 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 May 2015, the NYSPSC, which indicated that it would address enforcement at a later date, ordered CECONY, O&R and other gas utilities to perform risk assessment and remediation plans, additional leakage surveying and reporting; CECONY to hire an independent statistician to develop a risk assessment and remediation plan; and the gas utilities to implement certain new plastic fusion requirements. In October 2015, O&R submitted to the NYSPSC staff the company’s risk assessment and its recommendation that the development of a remediation plan is unnecessary and that the NYSPSC staff determine that the company’s risk assessment activities are complete. Regulatory Assets and Liabilities Regulatory assets and liabilities at September 30, 2015 and December 31, 2014 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Regulatory assets Unrecognized pension and other postretirement costs $4,208 $4,846 $4,008 $4,609 Future income tax 2,363 2,273 2,254 2,166 Environmental remediation costs 884 925 784 820 Revenue taxes 235 219 223 208 Deferred storm costs 218 319 137 224 Surcharge for New York State assessment 68 99 63 92 Unamortized loss on reacquired debt 52 57 50 55 Pension and other postretirement benefits deferrals 49 66 21 42 Net electric deferrals 49 63 49 63 O&R property tax reconciliation 45 36 — — Deferred derivative losses 32 25 28 23 Preferred stock redemption 26 27 26 27 O&R transition bond charges 22 27 — — Workers’ compensation 11 8 11 8 Recoverable energy costs 4 19 4 17 Other 179 147 162 127 Regulatory assets – noncurrent 8,445 9,156 7,820 8,481 Deferred derivative losses 57 97 52 92 Future income tax 9 10 — — Recoverable energy costs 1 41 1 40 Regulatory assets – current 67 148 53 132 Total Regulatory Assets $8,512 $9,304 $7,873 $8,613 Regulatory liabilities Allowance for cost of removal less salvage $633 $598 $530 $499 Property tax reconciliation 299 295 299 295 Base rate change deferrals 134 155 134 155 Net unbilled revenue deferrals 134 138 134 138 Prudence proceeding 100 105 100 105 Pension and other postretirement benefit deferrals 76 46 46 37 Variable-rate tax-exempt debt – cost rate reconciliation 75 78 64 78 New York State income tax rate change 67 62 63 59 Property tax refunds 55 87 55 87 Carrying charges on repair allowance and bonus depreciation 50 58 49 57 Earnings sharing – electric and steam 37 19 37 18 Net utility plant reconciliations 31 21 31 20 World Trade Center settlement proceeds 26 41 26 41 Unrecognized other postretirement costs 20 — 20 — Other 203 290 167 248 Regulatory liabilities – noncurrent 1,940 1,993 1,755 1,837 Refundable energy costs 99 128 71 84 Revenue decoupling mechanism 41 30 39 30 Future income tax 20 24 20 24 Deferred derivative gains 5 5 5 4 Regulatory liabilities – current 165 187 135 142 Total Regulatory Liabilities $2,105 $2,180 $1,890 $1,979
CECONY
Public Utilities, General Disclosures [Line Items]
Regulatory Matters	Regulatory Matters Rate Plans CECONY — Electric In June 2015, the New York State Public Service Commission (NYSPSC) approved an April 2015 Joint Proposal entered into by CECONY, the staff of the NYSPSC and other parties. Under the Joint Proposal, the rate plan for 2016 does not include a rate increase or decrease. The rate plan for 2016 includes additional revenues from the amortization to income of net regulatory liabilities. The following table contains a summary of the rate plan for 2016: Effective period January 2016 – December 2016 Base rate changes None (a) Amortizations to income of net regulatory (assets) and liabilities Additional $123 million of net regulatory liabilities (b). Other revenue sources Continued retention of $90 million of annual transmission congestion revenues. Revenue decoupling mechanism Continued reconciliation of actual electric delivery revenues to those authorized in the rate plan. Recoverable energy costs Continued current rate recovery of purchased power and fuel costs (c). Negative revenue adjustments Continued potential penalties (up to $400 million annually) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support, the impact of new laws and environmental remediation to amounts reflected in rates (d). Net utility plant reconciliations Target levels reflected in rates are as follows: Average rate base $18,282 million Weighted average cost of capital (after-tax) 6.91 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. Cost of long-term debt 5.09 percent Common equity ratio 48 percent (a) The impact of 2014 and 2015 base rate changes under the current electric rate plan will continue to be deferred. $249 million of annual revenues collected from electric customers will continue to be subject to potential refund following NYSPSC staff review of certain costs. Revenues will continue to include $21 million as funding for major storm reserve. (b) Annual amortization of $107 million of the regulatory asset for deferred Superstorm Sandy and other major storm costs will continue. The costs recoverable from customers will be reduced by $4 million . The costs will no longer be subject to NYSPSC staff review and the recovery of the costs will no longer be subject to refund. (c) For transmission service provided pursuant to the open access transmission tariff of PJM Interconnection LLC (PJM), 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 the Federal Energy Regulatory Commission (FERC) a request that would substantially increase the charges for the transmission service. FERC has granted the request and rejected CECONY’s protests. CECONY is challenging the FERC’s decision. In August 2015, PJM submitted a request to FERC that, if approved by FERC, would further increase the charges. In September 2015, CECONY filed a protest to this increase. (d) Deferrals for property taxes will continue to be limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity. In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral of 30 percent of the amount reflected in rates. O&R New York – Electric and Gas In October 2015, the NYSPSC approved a June 2015 Joint Proposal entered into by O&R, the NYSPSC staff and other parties for new electric and gas rate plans. Under the Joint Proposal, the new rate plans are effective November 2015. The following tables contain a summary of the new rate plans: O&R New York - Electric Effective period November 2015 - October 2017 Base rate changes Yr. 1 - $9.3 million Amortizations to income of net regulatory (assets) and liabilities (a) Yr. 1 - $(8.5) million Revenue decoupling mechanism Continued reconciliation of actual electric delivery revenues to those authorized in the rate plan. Recoverable energy costs Continued current rate recovery of purchased power costs. Negative revenue adjustments Potential penalties (up to $4 million annually) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, major storms, property taxes, the impact of new laws and environmental remediation to amounts reflected in rates. Net utility plant reconciliations (b) Target levels reflected in rates are: Average rate base Yr. 1 - $763 million Weighted average cost of capital (after-tax) Yr. 1 - 7.10 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. Cost of long-term debt Yr. 1 - 5.42 percent Common equity ratio 48 percent (a) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a five-year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015. (b) Excludes electric advanced metering infrastructure as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2. O&R New York - Gas Effective period November 2015 - October 2018 Base rate changes Yr. 1 - $16.4 million Amortizations to income of net regulatory (assets) and liabilities (a) Yr. 1 - $(1.7) million Revenue decoupling mechanism Continued reconciliation of actual gas delivery revenues to those authorized in the rate plan, including through weather normalization clause. Recoverable energy costs Continued current rate recovery of purchased gas costs. Negative revenue adjustments Potential penalties (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $5.8 million in Yr. 3) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, property taxes, the impact of new laws and environmental remediation to amounts reflected in rates. Net utility plant reconciliations (b) Target levels reflected in rates are: Average rate base Yr. 1 - $366 million Weighted average cost of capital (after-tax) Yr. 1 - 7.10 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. Cost of long-term debt Yr. 1 - 5.42 percent Common equity ratio 48 percent (a) Reflects that the company will not recover from customers a total of approximately $14 million of regulatory assets for property tax and interest rate reconciliations. Amounts that will not be recovered from customers were charged-off in June 2015. (b) Excludes gas advanced metering infrastructure as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $0.5 million in year 1, $4.2 million in year 2 and $7.2 million in year 3. 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 September 30, 2015 , the company had collected an estimated $1,889 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 disputed 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. In September 2015, the company, the NYSPSC staff and others entered into a Joint Proposal to settle this proceeding and related matters. The Joint Proposal is subject to NYSPSC approval. Pursuant to the Joint Proposal, the company is required to credit $116 million to customers and, for the period 2017 through 2044, to not seek to recover from customers an aggregate $55 million relating to return on its capital expenditures. In addition, the company’s revenues that were made subject to potential refund in this proceeding would no longer be subject to refund. At September 30, 2015, the company had a $100 million regulatory liability for the remaining amount to be credited to customers related to this matter. 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 September 30, 2015 , CECONY and O&R incurred response and restoration costs for Superstorm Sandy of $509 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. Collection from customers of these costs is provided for under the Utilities' current electric rate plans. 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 May 2015, the NYSPSC, which indicated that it would address enforcement at a later date, ordered CECONY, O&R and other gas utilities to perform risk assessment and remediation plans, additional leakage surveying and reporting; CECONY to hire an independent statistician to develop a risk assessment and remediation plan; and the gas utilities to implement certain new plastic fusion requirements. In October 2015, O&R submitted to the NYSPSC staff the company’s risk assessment and its recommendation that the development of a remediation plan is unnecessary and that the NYSPSC staff determine that the company’s risk assessment activities are complete. Regulatory Assets and Liabilities Regulatory assets and liabilities at September 30, 2015 and December 31, 2014 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Regulatory assets Unrecognized pension and other postretirement costs $4,208 $4,846 $4,008 $4,609 Future income tax 2,363 2,273 2,254 2,166 Environmental remediation costs 884 925 784 820 Revenue taxes 235 219 223 208 Deferred storm costs 218 319 137 224 Surcharge for New York State assessment 68 99 63 92 Unamortized loss on reacquired debt 52 57 50 55 Pension and other postretirement benefits deferrals 49 66 21 42 Net electric deferrals 49 63 49 63 O&R property tax reconciliation 45 36 — — Deferred derivative losses 32 25 28 23 Preferred stock redemption 26 27 26 27 O&R transition bond charges 22 27 — — Workers’ compensation 11 8 11 8 Recoverable energy costs 4 19 4 17 Other 179 147 162 127 Regulatory assets – noncurrent 8,445 9,156 7,820 8,481 Deferred derivative losses 57 97 52 92 Future income tax 9 10 — — Recoverable energy costs 1 41 1 40 Regulatory assets – current 67 148 53 132 Total Regulatory Assets $8,512 $9,304 $7,873 $8,613 Regulatory liabilities Allowance for cost of removal less salvage $633 $598 $530 $499 Property tax reconciliation 299 295 299 295 Base rate change deferrals 134 155 134 155 Net unbilled revenue deferrals 134 138 134 138 Prudence proceeding 100 105 100 105 Pension and other postretirement benefit deferrals 76 46 46 37 Variable-rate tax-exempt debt – cost rate reconciliation 75 78 64 78 New York State income tax rate change 67 62 63 59 Property tax refunds 55 87 55 87 Carrying charges on repair allowance and bonus depreciation 50 58 49 57 Earnings sharing – electric and steam 37 19 37 18 Net utility plant reconciliations 31 21 31 20 World Trade Center settlement proceeds 26 41 26 41 Unrecognized other postretirement costs 20 — 20 — Other 203 290 167 248 Regulatory liabilities – noncurrent 1,940 1,993 1,755 1,837 Refundable energy costs 99 128 71 84 Revenue decoupling mechanism 41 30 39 30 Future income tax 20 24 20 24 Deferred derivative gains 5 5 5 4 Regulatory liabilities – current 165 187 135 142 Total Regulatory Liabilities $2,105 $2,180 $1,890 $1,979

Capitalization

Capitalization	9 Months Ended
	Sep. 30, 2015
Debt Instrument [Line Items]
Capitalization	Capitalization In April 2015, O&R redeemed at maturity $40 million of 5.30 percent 10 -year debentures. In June 2015, O&R issued $120 million aggregate principal amount of 4.95 percent debentures, due 2045 . Also in June 2015, a Con Edison Development subsidiary issued $118 million aggregate principal amount of 3.94 percent senior notes, due 2036 . The notes are secured by four of the company's solar projects. In August 2015, O&R redeemed at maturity $55 million of 2.50 percent 5 -year debentures and $44 million of variable rate tax-exempt 20 -year debt. The carrying amounts and fair values of long-term debt at September 30, 2015 and December 31, 2014 are: (Millions of Dollars) 2015 2014 Long-Term Debt (including current portion) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $12,282 $13,575 $12,191 $13,998 CECONY $11,215 $12,385 $11,214 $12,846 Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,939 million and $636 million of the fair value of long-term debt at September 30, 2015 are classified as Level 2 and Level 3, respectively. For CECONY, $11,749 million and $636 million of the fair value of long-term debt at September 30, 2015 are classified as Level 2 and Level 3, respectively (see Note L). 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.
CECONY
Debt Instrument [Line Items]
Capitalization	Capitalization In April 2015, O&R redeemed at maturity $40 million of 5.30 percent 10 -year debentures. In June 2015, O&R issued $120 million aggregate principal amount of 4.95 percent debentures, due 2045 . Also in June 2015, a Con Edison Development subsidiary issued $118 million aggregate principal amount of 3.94 percent senior notes, due 2036 . The notes are secured by four of the company's solar projects. In August 2015, O&R redeemed at maturity $55 million of 2.50 percent 5 -year debentures and $44 million of variable rate tax-exempt 20 -year debt. The carrying amounts and fair values of long-term debt at September 30, 2015 and December 31, 2014 are: (Millions of Dollars) 2015 2014 Long-Term Debt (including current portion) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $12,282 $13,575 $12,191 $13,998 CECONY $11,215 $12,385 $11,214 $12,846 Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,939 million and $636 million of the fair value of long-term debt at September 30, 2015 are classified as Level 2 and Level 3, respectively. For CECONY, $11,749 million and $636 million of the fair value of long-term debt at September 30, 2015 are classified as Level 2 and Level 3, respectively (see Note L). 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.

Short-Term Borrowing

Short-Term Borrowing	9 Months Ended
	Sep. 30, 2015
Short-Term Borrowing	Short-Term Borrowing At September 30, 2015 , Con Edison had $1,160 million of commercial paper outstanding of which $649 million was outstanding under CECONY’s program. The weighted average interest rate at September 30, 2015 was 0.3 percent for both Con Edison and CECONY. 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 September 30, 2015 and December 31, 2014 , no loans were outstanding under the credit agreement (Credit Agreement) and $56 million (including $11 million for CECONY) and $11 million (including $11 million for CECONY), respectively, of letters of credit were outstanding under the Credit Agreement.
CECONY
Short-Term Borrowing	Short-Term Borrowing At September 30, 2015 , Con Edison had $1,160 million of commercial paper outstanding of which $649 million was outstanding under CECONY’s program. The weighted average interest rate at September 30, 2015 was 0.3 percent for both Con Edison and CECONY. 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 September 30, 2015 and December 31, 2014 , no loans were outstanding under the credit agreement (Credit Agreement) and $56 million (including $11 million for CECONY) and $11 million (including $11 million for CECONY), respectively, of letters of credit were outstanding under the Credit Agreement.

Pension Benefits

Pension Benefits	9 Months Ended
	Sep. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Pension Benefits	Pension Benefits Total Periodic Benefit Cost The components of the Companies’ total periodic benefit costs for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost – including administrative expenses $74 $57 $70 $53 Interest cost on projected benefit obligation 144 143 135 134 Expected return on plan assets (222) (208) (210) (198) Recognition of net actuarial loss 194 154 183 146 Recognition of prior service costs 1 1 — 1 NET PERIODIC BENEFIT COST $191 $147 $178 $136 Amortization of regulatory asset 1 1 1 1 TOTAL PERIODIC BENEFIT COST $192 $148 $179 $137 Cost capitalized (80) (57) (76) (54) Reconciliation to rate level (14) 30 (14) 28 Cost charged to operating expenses $98 $121 $89 $111 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost – including administrative expenses $223 $170 $209 $158 Interest cost on projected benefit obligation 431 429 404 402 Expected return on plan assets (664) (624) (630) (592) Recognition of net actuarial loss 581 464 550 439 Recognition of prior service costs 3 3 1 2 NET PERIODIC BENEFIT COST $574 $442 $534 $409 Amortization of regulatory asset 2 2 2 2 TOTAL PERIODIC BENEFIT COST $576 $444 $536 $411 Cost capitalized (224) (166) (214) (156) Reconciliation to rate level (56) 86 (56) 78 Cost charged to operating expenses $296 $364 $266 $333 Expected Contributions Based on estimates as of September 30, 2015 , the Companies expect to make contributions to the pension plans during 2015 of $750 million (of which $697 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 supplemental plans. During the first nine months of 2015 , the Companies contributed $747 million (of which $694 million was contributed by CECONY) to the pension plans. CECONY also contributed $16 million to its external trust for supplemental plans.
CECONY
Defined Benefit Plan Disclosure [Line Items]
Pension Benefits	Pension Benefits Total Periodic Benefit Cost The components of the Companies’ total periodic benefit costs for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost – including administrative expenses $74 $57 $70 $53 Interest cost on projected benefit obligation 144 143 135 134 Expected return on plan assets (222) (208) (210) (198) Recognition of net actuarial loss 194 154 183 146 Recognition of prior service costs 1 1 — 1 NET PERIODIC BENEFIT COST $191 $147 $178 $136 Amortization of regulatory asset 1 1 1 1 TOTAL PERIODIC BENEFIT COST $192 $148 $179 $137 Cost capitalized (80) (57) (76) (54) Reconciliation to rate level (14) 30 (14) 28 Cost charged to operating expenses $98 $121 $89 $111 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost – including administrative expenses $223 $170 $209 $158 Interest cost on projected benefit obligation 431 429 404 402 Expected return on plan assets (664) (624) (630) (592) Recognition of net actuarial loss 581 464 550 439 Recognition of prior service costs 3 3 1 2 NET PERIODIC BENEFIT COST $574 $442 $534 $409 Amortization of regulatory asset 2 2 2 2 TOTAL PERIODIC BENEFIT COST $576 $444 $536 $411 Cost capitalized (224) (166) (214) (156) Reconciliation to rate level (56) 86 (56) 78 Cost charged to operating expenses $296 $364 $266 $333 Expected Contributions Based on estimates as of September 30, 2015 , the Companies expect to make contributions to the pension plans during 2015 of $750 million (of which $697 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 supplemental plans. During the first nine months of 2015 , the Companies contributed $747 million (of which $694 million was contributed by CECONY) to the pension plans. CECONY also contributed $16 million to its external trust for supplemental plans.

Other Postretirement Benefits

Other Postretirement Benefits	9 Months Ended
	Sep. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Other Postretirement Benefits	Other Postretirement Benefits Total Periodic Benefit Cost The components of the Companies’ total periodic other postretirement benefit costs for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost $5 $5 $4 $4 Interest cost on accumulated other postretirement benefit obligation 13 15 11 13 Expected return on plan assets (20) (19) (17) (17) Recognition of net actuarial loss 8 14 7 13 Recognition of prior service cost (5) (5) (4) (4) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST $1 $10 $1 $9 Cost capitalized (1) (4) (1) (4) Reconciliation to rate level 4 3 2 1 Cost charged to operating expenses $4 $9 $2 $6 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost $15 $14 $11 $11 Interest cost on accumulated other postretirement benefit obligation 38 45 32 39 Expected return on plan assets (59) (58) (51) (51) Recognition of net actuarial loss 24 43 21 38 Recognition of prior service cost (15) (14) (10) (11) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST $3 $30 $3 $26 Cost capitalized (2) (11) (2) (10) Reconciliation to rate level 12 8 5 2 Cost charged to operating expenses $13 $27 $6 $18 Contributions The Companies made a contribution of $6 million , nearly all of which is for CECONY, to the other postretirement benefit plans in 2015 . The Companies’ policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.
CECONY
Defined Benefit Plan Disclosure [Line Items]
Other Postretirement Benefits	Other Postretirement Benefits Total Periodic Benefit Cost The components of the Companies’ total periodic other postretirement benefit costs for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost $5 $5 $4 $4 Interest cost on accumulated other postretirement benefit obligation 13 15 11 13 Expected return on plan assets (20) (19) (17) (17) Recognition of net actuarial loss 8 14 7 13 Recognition of prior service cost (5) (5) (4) (4) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST $1 $10 $1 $9 Cost capitalized (1) (4) (1) (4) Reconciliation to rate level 4 3 2 1 Cost charged to operating expenses $4 $9 $2 $6 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost $15 $14 $11 $11 Interest cost on accumulated other postretirement benefit obligation 38 45 32 39 Expected return on plan assets (59) (58) (51) (51) Recognition of net actuarial loss 24 43 21 38 Recognition of prior service cost (15) (14) (10) (11) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST $3 $30 $3 $26 Cost capitalized (2) (11) (2) (10) Reconciliation to rate level 12 8 5 2 Cost charged to operating expenses $13 $27 $6 $18 Contributions The Companies made a contribution of $6 million , nearly all of which is for CECONY, to the other postretirement benefit plans in 2015 . The Companies’ policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

Environmental Matters

Environmental Matters	9 Months Ended
	Sep. 30, 2015
Site Contingency [Line Items]
Environmental Matters	Environmental Matters Superfund Sites Hazardous substances, such as asbestos, polychlorinated biphenyls (PCBs) and coal tar, have been used or generated in the course of operations of the Utilities and their predecessors and are present at sites and in facilities and equipment they currently or previously owned, including sites at which gas was manufactured or stored. The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances for investigation and remediation costs (which include costs of demolition, removal, disposal, storage, replacement, containment and monitoring) and natural resource damages. Liability under these laws can be material and may be imposed for contamination from past acts, even though such past acts may have been lawful at the time they occurred. The sites at which the Utilities have been asserted to have liability under these laws, including their manufactured gas plant sites and any neighboring areas to which contamination may have migrated, are referred to herein as “Superfund Sites.” For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of the undiscounted cost to investigate the sites and, for sites that have been investigated in whole or in part, the cost to remediate the sites, if remediation is necessary and if a reasonable estimate of such cost can be made. Remediation costs are estimated in light of the information available, applicable remediation standards and experience with similar sites. The accrued liabilities and regulatory assets related to Superfund Sites at September 30, 2015 and December 31, 2014 were as follows: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Accrued Liabilities: Manufactured gas plant sites $666 $684 $572 $587 Other Superfund Sites 80 80 79 79 Total $746 $764 $651 $666 Regulatory assets $884 $925 $784 $820 Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The 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 for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Remediation costs incurred $6 $5 $6 $2 Insurance recoveries received — — — — For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Remediation costs incurred $21 $19 $18 $12 Insurance recoveries received (a) — 5 — 5 (a) 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 September 30, 2015 and December 31, 2014 , 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 September 30, 2015 and December 31, 2014 were as follows: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $86 $83 $81 $78 Regulatory assets – workers’ compensation $11 $8 $11 $8
CECONY
Site Contingency [Line Items]
Environmental Matters	Environmental Matters Superfund Sites Hazardous substances, such as asbestos, polychlorinated biphenyls (PCBs) and coal tar, have been used or generated in the course of operations of the Utilities and their predecessors and are present at sites and in facilities and equipment they currently or previously owned, including sites at which gas was manufactured or stored. The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances for investigation and remediation costs (which include costs of demolition, removal, disposal, storage, replacement, containment and monitoring) and natural resource damages. Liability under these laws can be material and may be imposed for contamination from past acts, even though such past acts may have been lawful at the time they occurred. The sites at which the Utilities have been asserted to have liability under these laws, including their manufactured gas plant sites and any neighboring areas to which contamination may have migrated, are referred to herein as “Superfund Sites.” For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of the undiscounted cost to investigate the sites and, for sites that have been investigated in whole or in part, the cost to remediate the sites, if remediation is necessary and if a reasonable estimate of such cost can be made. Remediation costs are estimated in light of the information available, applicable remediation standards and experience with similar sites. The accrued liabilities and regulatory assets related to Superfund Sites at September 30, 2015 and December 31, 2014 were as follows: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Accrued Liabilities: Manufactured gas plant sites $666 $684 $572 $587 Other Superfund Sites 80 80 79 79 Total $746 $764 $651 $666 Regulatory assets $884 $925 $784 $820 Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The 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 for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Remediation costs incurred $6 $5 $6 $2 Insurance recoveries received — — — — For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Remediation costs incurred $21 $19 $18 $12 Insurance recoveries received (a) — 5 — 5 (a) 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 September 30, 2015 and December 31, 2014 , 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 September 30, 2015 and December 31, 2014 were as follows: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $86 $83 $81 $78 Regulatory assets – workers’ compensation $11 $8 $11 $8

Other Material Contingencies

Other Material Contingencies	9 Months Ended
	Sep. 30, 2015
Guarantor Obligations [Line Items]
Other Material Contingencies	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 90 suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for wrongful death, 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 September 30, 2015 , 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 116 th and 117 th 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 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC (which is also conducting an investigation). In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. Approximately 70 suits are pending against the company seeking generally unspecified damages and, in one case, punitive damages, for wrongful death, 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 September 30, 2015 , the company had not accrued a liability for the incident. Other Contingencies See “Other Regulatory Matters” in Note B and “Uncertain Tax Positions” in Note I. 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 $2,576 million and $2,547 million at September 30, 2015 and December 31, 2014 , respectively. A summary, by type and term, of Con Edison’s total guarantees at September 30, 2015 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) NY Transco $946 $413 $— $1,359 Energy transactions 760 36 89 885 Renewable electric production projects 176 82 44 302 Other 30 — — 30 Total $1,912 $531 $133 $2,576 NY Transco — Con Edison has guaranteed payment by its subsidiary, Con Edison Transmission, of the contributions it agreed to make to 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 of the projects would be subject to authorizations from the NYSPSC, the 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 assumes that all of 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 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 for $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 September 30, 2015 .
CECONY
Guarantor Obligations [Line Items]
Other Material Contingencies	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 90 suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for wrongful death, 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 September 30, 2015 , 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 116 th and 117 th 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 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC (which is also conducting an investigation). In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. Approximately 70 suits are pending against the company seeking generally unspecified damages and, in one case, punitive damages, for wrongful death, 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 September 30, 2015 , the company had not accrued a liability for the incident. Other Contingencies See “Other Regulatory Matters” in Note B and “Uncertain Tax Positions” in Note I. 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 $2,576 million and $2,547 million at September 30, 2015 and December 31, 2014 , respectively. A summary, by type and term, of Con Edison’s total guarantees at September 30, 2015 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) NY Transco $946 $413 $— $1,359 Energy transactions 760 36 89 885 Renewable electric production projects 176 82 44 302 Other 30 — — 30 Total $1,912 $531 $133 $2,576 NY Transco — Con Edison has guaranteed payment by its subsidiary, Con Edison Transmission, of the contributions it agreed to make to 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 of the projects would be subject to authorizations from the NYSPSC, the 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 assumes that all of 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 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 for $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 September 30, 2015 .

Income Tax

Income Tax	9 Months Ended
	Sep. 30, 2015
Income Tax Examination [Line Items]
Income Tax	Income Tax Con Edison’s income tax expense decreased to $249 million for the three months ended September 30, 2015 from $259 million for the three months ended September 30, 2014 . Con Edison's effective tax rate for the three months ended September 30, 2015 and 2014 was 37 percent . CECONY’s income tax expense decreased to $222 million for the three months ended September 30, 2015 from $233 million for the three months ended September 30, 2014 . CECONY's effective tax rate for the three months ended September 30, 2015 and 2014 was 37 percent . Con Edison’s income tax expense decreased to $548 million for the nine months ended September 30, 2015 from $559 million for the nine months ended September 30, 2014 . Con Edison's effective tax rate for the nine months ended September 30, 2015 and 2014 was 35 percent and 36 percent , respectively. The decrease in Con Edison’s effective tax rate is due primarily to higher production tax credits and amortization of investment tax credits from the competitive energy businesses. CECONY’s income tax expense increased to $515 million for the nine months ended September 30, 2015 from $496 million for the nine months ended September 30, 2014 . CECONY's effective tax rate for the nine months ended September 30, 2015 and 2014 was 35 percent . In September 2015, Con Edison and subsidiaries filed its 2014 federal income tax return. As part of the filing, the company generated excess income tax credits (principally investment tax credits). The company plans to carryback a portion of the excess tax credits to the 2013 federal income tax return and request a tax refund of $30 million . Uncertain Tax Positions At September 30, 2015 , the estimated liability for uncertain tax positions for Con Edison was $34 million ( $2 million for CECONY). Con Edison reasonably expects to resolve approximately $25 million ( $16 million , net of federal taxes) of its uncertain tax positions within the next twelve months, of which the entire amount, if recognized, 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 total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $34 million ( $22 million , net of federal taxes). 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 the three and nine months ended September 30, 2015 , Con Edison recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in its consolidated income statements. At September 30, 2015 and December 31, 2014 , Con Edison recognized an immaterial amount of accrued interest on its consolidated balance sheets.
CECONY
Income Tax Examination [Line Items]
Income Tax	Income Tax Con Edison’s income tax expense decreased to $249 million for the three months ended September 30, 2015 from $259 million for the three months ended September 30, 2014 . Con Edison's effective tax rate for the three months ended September 30, 2015 and 2014 was 37 percent . CECONY’s income tax expense decreased to $222 million for the three months ended September 30, 2015 from $233 million for the three months ended September 30, 2014 . CECONY's effective tax rate for the three months ended September 30, 2015 and 2014 was 37 percent . Con Edison’s income tax expense decreased to $548 million for the nine months ended September 30, 2015 from $559 million for the nine months ended September 30, 2014 . Con Edison's effective tax rate for the nine months ended September 30, 2015 and 2014 was 35 percent and 36 percent , respectively. The decrease in Con Edison’s effective tax rate is due primarily to higher production tax credits and amortization of investment tax credits from the competitive energy businesses. CECONY’s income tax expense increased to $515 million for the nine months ended September 30, 2015 from $496 million for the nine months ended September 30, 2014 . CECONY's effective tax rate for the nine months ended September 30, 2015 and 2014 was 35 percent . In September 2015, Con Edison and subsidiaries filed its 2014 federal income tax return. As part of the filing, the company generated excess income tax credits (principally investment tax credits). The company plans to carryback a portion of the excess tax credits to the 2013 federal income tax return and request a tax refund of $30 million . Uncertain Tax Positions At September 30, 2015 , the estimated liability for uncertain tax positions for Con Edison was $34 million ( $2 million for CECONY). Con Edison reasonably expects to resolve approximately $25 million ( $16 million , net of federal taxes) of its uncertain tax positions within the next twelve months, of which the entire amount, if recognized, 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 total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $34 million ( $22 million , net of federal taxes). 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 the three and nine months ended September 30, 2015 , Con Edison recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in its consolidated income statements. At September 30, 2015 and December 31, 2014 , Con Edison recognized an immaterial amount of accrued interest on its consolidated balance sheets.

Financial Information by Busine

Financial Information by Business Segment	9 Months Ended
	Sep. 30, 2015
Segment Reporting Information [Line Items]
Financial Information by Business Segment	Financial Information by Business Segment The financial data for the business segments are as follows: For the Three Months Ended September 30, Operating revenues Inter-segment revenues Depreciation and amortization Operating income (Millions of Dollars) 2015 2014 2015 2014 2015 2014 2015 2014 CECONY Electric $2,558 $2,582 $4 $4 $207 $198 $811 $811 Gas 213 210 1 1 35 33 (17) (14) Steam 58 46 22 21 20 19 (49) (41) Consolidation adjustments — — (27) (26) — — — — Total CECONY $2,829 $2,838 $— $— $262 $250 $745 $756 O&R Electric $205 $205 $— $— $13 $12 $51 $51 Gas 24 27 — — 4 4 (9) (8) Total O&R $229 $232 $— $— $17 $16 $42 $43 Competitive energy businesses $386 $321 $(2) $(3) $6 $3 $43 $20 Other (a) (1) (1) 2 3 — 1 — — Total Con Edison $3,443 $3,390 $— $— $285 $270 $830 $819 (a) Parent company and consolidation adjustments. Other does not represent a business segment. For the Nine Months Ended September 30, Operating revenues Inter-segment revenues Depreciation and amortization Operating income (Millions of Dollars) 2015 2014 2015 2014 2015 2014 2015 2014 CECONY Electric $6,416 $6,635 $13 $12 $610 $581 $1,511 $1,416 Gas 1,177 1,359 4 4 105 98 278 273 Steam 529 485 65 62 58 58 100 97 Consolidation adjustments — — (82) (78) — — — — Total CECONY $8,122 $8,479 $— $— $773 $737 $1,889 $1,786 O&R Electric $523 $525 $— $— $38 $33 $85 $87 Gas 117 155 — — 13 12 — 15 Total O&R $640 $680 $— $— $51 $45 $85 $102 Competitive energy businesses $1,087 $934 $(5) $(2) $16 $14 $53 $70 Other (a) (2) (2) 5 2 — — 1 1 Total Con Edison $9,847 $10,091 $— $— $840 $796 $2,028 $1,959 (a) Parent company and consolidation adjustments. Other does not represent a business segment.
CECONY
Segment Reporting Information [Line Items]
Financial Information by Business Segment	Financial Information by Business Segment The financial data for the business segments are as follows: For the Three Months Ended September 30, Operating revenues Inter-segment revenues Depreciation and amortization Operating income (Millions of Dollars) 2015 2014 2015 2014 2015 2014 2015 2014 CECONY Electric $2,558 $2,582 $4 $4 $207 $198 $811 $811 Gas 213 210 1 1 35 33 (17) (14) Steam 58 46 22 21 20 19 (49) (41) Consolidation adjustments — — (27) (26) — — — — Total CECONY $2,829 $2,838 $— $— $262 $250 $745 $756 O&R Electric $205 $205 $— $— $13 $12 $51 $51 Gas 24 27 — — 4 4 (9) (8) Total O&R $229 $232 $— $— $17 $16 $42 $43 Competitive energy businesses $386 $321 $(2) $(3) $6 $3 $43 $20 Other (a) (1) (1) 2 3 — 1 — — Total Con Edison $3,443 $3,390 $— $— $285 $270 $830 $819 (a) Parent company and consolidation adjustments. Other does not represent a business segment. For the Nine Months Ended September 30, Operating revenues Inter-segment revenues Depreciation and amortization Operating income (Millions of Dollars) 2015 2014 2015 2014 2015 2014 2015 2014 CECONY Electric $6,416 $6,635 $13 $12 $610 $581 $1,511 $1,416 Gas 1,177 1,359 4 4 105 98 278 273 Steam 529 485 65 62 58 58 100 97 Consolidation adjustments — — (82) (78) — — — — Total CECONY $8,122 $8,479 $— $— $773 $737 $1,889 $1,786 O&R Electric $523 $525 $— $— $38 $33 $85 $87 Gas 117 155 — — 13 12 — 15 Total O&R $640 $680 $— $— $51 $45 $85 $102 Competitive energy businesses $1,087 $934 $(5) $(2) $16 $14 $53 $70 Other (a) (2) (2) 5 2 — — 1 1 Total Con Edison $9,847 $10,091 $— $— $840 $796 $2,028 $1,959 (a) Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	9 Months Ended
	Sep. 30, 2015
Derivative [Line Items]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the balance sheet at fair value (see Note L), 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 September 30, 2015 and December 31, 2014 were: (Millions of Dollars) 2015 2014 Balance Sheet Location Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Con Edison Fair value of derivative assets Current $47 $(33) $14 (b) $111 $(67) $44 (b) Current - assets held for sale (c) 39 (39) — — — — Noncurrent 19 (17) 2 34 (23) 11 Total fair value of derivative assets $105 $(89) $16 $145 $(90) $55 Fair value of derivative liabilities Current $(84) $58 $(26) $(242) $139 $(103) Current - liabilities held for sale (c) (77) 30 (47) — — — Noncurrent (48) 31 (17) (66) 91 25 Noncurrent - liabilities held for sale (c) (31) 9 (22) — — — Total fair value of derivative liabilities $(240) $128 $(112) $(308) $230 $(78) Net fair value derivative assets/(liabilities) $(135) $39 $(96) (b) $(163) $140 $(23) (b) CECONY Fair value of derivative assets Current $36 $(28) $8 (b) $26 $(15) $11 (b) Noncurrent 16 (15) 1 22 (20) 2 Total fair value of derivative assets $52 $(43) $9 $48 $(35) $13 Fair value of derivative liabilities Current $(72) $53 $(19) $(96) $48 $(48) Noncurrent (42) 28 (14) (42) 32 (10) Total fair value of derivative liabilities $(114) $81 $(33) $(138) $80 $(58) Net fair value derivative assets/(liabilities) $(62) $38 $(24) (b) $(90) $45 $(45) (b) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At September 30, 2015 and December 31, 2014 , margin deposits for Con Edison ( $17 million and $27 million , respectively) and CECONY ( $17 million and $25 million , respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet (see Note O). The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or 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 three and nine months ended September 30, 2015 and 2014 : For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2015 2014 2015 2014 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $(1) $(6) $(1) $(5) Noncurrent Deferred derivative gains — (5) — (5) Total deferred gains/(losses) $(1) $(11) $(1) $(10) Current Deferred derivative losses $8 $(6) $8 $(5) Current Recoverable energy costs (53) (33) (49) (29) Noncurrent Deferred derivative losses 14 3 13 3 Total deferred gains/(losses) $(31) $(36) $(28) $(31) Net deferred gains/(losses) $(32) $(47) $(29) $(41) Income Statement Location Pre-tax gain/(loss) recognized in income Purchased power expense $(31) (a) $(28) (b) $— $— Gas purchased for resale (26) (29) — — Non-utility revenue 5 (a) 20 (b) — — Total pre-tax gain/(loss) recognized in income $(52) $(37) $— $— (a) For the three months ended September 30, 2015 , Con Edison recorded in purchased power expense an unrealized pre-tax gain of $12 million . (b) For the three months ended September 30, 2014 , Con Edison recorded in purchased power expense an unrealized pre-tax loss of $(1) million . For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2015 2014 2015 2014 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $— $25 $1 $20 Noncurrent Deferred derivative gains — 1 — 1 Total deferred gains/(losses) $— $26 $1 $21 Current Deferred derivative losses $40 $10 $40 $10 Current Recoverable energy costs (92) 54 (87) 41 Noncurrent Deferred derivative losses (7) 3 (5) 2 Total deferred gains/(losses) $(59) $67 $(52) $53 Net deferred gains/(losses) $(59) $93 $(51) $74 Income Statement Location Pre-tax gain/(loss) recognized in income Purchased power expense $(60) (a) $134 (b) $— $— Gas purchased for resale (94) (75) — — Non-utility revenue 20 (a) 10 (b) — — Total pre-tax gain/(loss) recognized in income $(134) $69 $— $— (a) For the nine months ended September 30, 2015 , Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ( $3 million loss) and purchased power expense ( $6 million gain). (b) For the nine months ended September 30, 2014 , Con Edison recorded in purchased power expense an unrealized pre-tax gain of $14 million . The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at September 30, 2015 : Electric Energy (MWHs) (a)(b) Capacity (MWs) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison (c) 18,475,688 7,201 63,386,967 4,620,000 CECONY 5,972,325 2,400 56,690,000 4,620,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes. (c) Includes 11,445,799 MWHs for electric energy, 5,436 MWs for capacity and 509,294 Dt for natural gas derivative transactions that are held for sale. 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 to offset. At September 30, 2015 , Con Edison and CECONY had $154 million and $17 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $71 million with commodity exchange brokers, $69 million with independent system operators, $7 million with investment-grade counterparties and $7 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 September 30, 2015 : (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $52 $32 Collateral posted 5 — Additional collateral (b) (downgrade one level from current ratings) 1 — Additional collateral (b) (downgrade to below investment grade from current ratings) 72 (c) 43 (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 the competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $3 million at September 30, 2015 . 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 to offset. (c) Derivative instruments that are net assets have been excluded from the table. At September 30, 2015 , if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $9 million .
CECONY
Derivative [Line Items]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the balance sheet at fair value (see Note L), 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 September 30, 2015 and December 31, 2014 were: (Millions of Dollars) 2015 2014 Balance Sheet Location Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Con Edison Fair value of derivative assets Current $47 $(33) $14 (b) $111 $(67) $44 (b) Current - assets held for sale (c) 39 (39) — — — — Noncurrent 19 (17) 2 34 (23) 11 Total fair value of derivative assets $105 $(89) $16 $145 $(90) $55 Fair value of derivative liabilities Current $(84) $58 $(26) $(242) $139 $(103) Current - liabilities held for sale (c) (77) 30 (47) — — — Noncurrent (48) 31 (17) (66) 91 25 Noncurrent - liabilities held for sale (c) (31) 9 (22) — — — Total fair value of derivative liabilities $(240) $128 $(112) $(308) $230 $(78) Net fair value derivative assets/(liabilities) $(135) $39 $(96) (b) $(163) $140 $(23) (b) CECONY Fair value of derivative assets Current $36 $(28) $8 (b) $26 $(15) $11 (b) Noncurrent 16 (15) 1 22 (20) 2 Total fair value of derivative assets $52 $(43) $9 $48 $(35) $13 Fair value of derivative liabilities Current $(72) $53 $(19) $(96) $48 $(48) Noncurrent (42) 28 (14) (42) 32 (10) Total fair value of derivative liabilities $(114) $81 $(33) $(138) $80 $(58) Net fair value derivative assets/(liabilities) $(62) $38 $(24) (b) $(90) $45 $(45) (b) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At September 30, 2015 and December 31, 2014 , margin deposits for Con Edison ( $17 million and $27 million , respectively) and CECONY ( $17 million and $25 million , respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet (see Note O). The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or 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 three and nine months ended September 30, 2015 and 2014 : For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2015 2014 2015 2014 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $(1) $(6) $(1) $(5) Noncurrent Deferred derivative gains — (5) — (5) Total deferred gains/(losses) $(1) $(11) $(1) $(10) Current Deferred derivative losses $8 $(6) $8 $(5) Current Recoverable energy costs (53) (33) (49) (29) Noncurrent Deferred derivative losses 14 3 13 3 Total deferred gains/(losses) $(31) $(36) $(28) $(31) Net deferred gains/(losses) $(32) $(47) $(29) $(41) Income Statement Location Pre-tax gain/(loss) recognized in income Purchased power expense $(31) (a) $(28) (b) $— $— Gas purchased for resale (26) (29) — — Non-utility revenue 5 (a) 20 (b) — — Total pre-tax gain/(loss) recognized in income $(52) $(37) $— $— (a) For the three months ended September 30, 2015 , Con Edison recorded in purchased power expense an unrealized pre-tax gain of $12 million . (b) For the three months ended September 30, 2014 , Con Edison recorded in purchased power expense an unrealized pre-tax loss of $(1) million . For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2015 2014 2015 2014 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $— $25 $1 $20 Noncurrent Deferred derivative gains — 1 — 1 Total deferred gains/(losses) $— $26 $1 $21 Current Deferred derivative losses $40 $10 $40 $10 Current Recoverable energy costs (92) 54 (87) 41 Noncurrent Deferred derivative losses (7) 3 (5) 2 Total deferred gains/(losses) $(59) $67 $(52) $53 Net deferred gains/(losses) $(59) $93 $(51) $74 Income Statement Location Pre-tax gain/(loss) recognized in income Purchased power expense $(60) (a) $134 (b) $— $— Gas purchased for resale (94) (75) — — Non-utility revenue 20 (a) 10 (b) — — Total pre-tax gain/(loss) recognized in income $(134) $69 $— $— (a) For the nine months ended September 30, 2015 , Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ( $3 million loss) and purchased power expense ( $6 million gain). (b) For the nine months ended September 30, 2014 , Con Edison recorded in purchased power expense an unrealized pre-tax gain of $14 million . The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at September 30, 2015 : Electric Energy (MWHs) (a)(b) Capacity (MWs) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison (c) 18,475,688 7,201 63,386,967 4,620,000 CECONY 5,972,325 2,400 56,690,000 4,620,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes. (c) Includes 11,445,799 MWHs for electric energy, 5,436 MWs for capacity and 509,294 Dt for natural gas derivative transactions that are held for sale. 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 to offset. At September 30, 2015 , Con Edison and CECONY had $154 million and $17 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $71 million with commodity exchange brokers, $69 million with independent system operators, $7 million with investment-grade counterparties and $7 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 September 30, 2015 : (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $52 $32 Collateral posted 5 — Additional collateral (b) (downgrade one level from current ratings) 1 — Additional collateral (b) (downgrade to below investment grade from current ratings) 72 (c) 43 (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 the competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $3 million at September 30, 2015 . 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 to offset. (c) Derivative instruments that are net assets have been excluded from the table. At September 30, 2015 , if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $9 million .

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements	Fair Value Measurements The accounting rules for fair value measurements and disclosures define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. The accounting rules for fair value measurements and disclosures established a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows: • Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange. • Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models. • Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value. Assets and liabilities measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 are summarized below. 2015 2014 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $1 $15 $11 $6 $33 $3 $78 $28 $(27) $82 Commodity held for sale (f) — 37 — (37) — — — — — — Other (a)(b)(d) 181 112 — — 293 163 116 — — 279 Total assets $182 $164 $11 $(31) $326 $166 $194 $28 $(27) $361 Derivative liabilities: Commodity (a)(b)(c) $12 $80 $1 $(50) $43 $18 $246 $8 $(194) $78 Commodity held for sale (f) 2 99 6 (38) 69 — — — — — Total liabilities $14 $179 $7 $(88) $112 $18 $246 $8 $(194) $78 CECONY Derivative assets: Commodity (a)(b)(c) $1 $7 $8 $10 $26 $1 $3 $13 $21 $38 Other (a)(b)(d) 167 104 — — 271 155 106 — — 261 Total assets $168 $111 $8 $10 $297 $156 $109 $13 $21 $299 Derivative liabilities: Commodity (a)(b)(c) $11 $67 $— $(45) $33 $16 $91 $— $(49) $58 (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 nine months ended September 30, 2015 and for the year ended December 31, 2014 . (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2015 and December 31, 2014 , the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties. (f) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet (see Note O). 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 September 30, 2015 Valuation Techniques Unobservable Inputs Range (Millions of Dollars) Con Edison – Commodity Electricity $(5) Discounted Cash Flow Forward energy prices (a) $18.50-$91.75 per MWH Discounted Cash Flow Forward capacity prices (a) $2.96-$15.01 per kW-month Transmission Congestion Contracts/Financial Transmission Rights 9 Discounted Cash Flow Discount to adjust auction prices for inter-zonal forward price curves (b) 40.8%-57.9% Discount to adjust auction prices for historical monthly realized settlements (b) 37.5%-82.2% Inter-zonal forward price curves adjusted for historical zonal losses (b) $(5.30)-$2.94 per MWH Total Con Edison—Commodity $4 CECONY—Commodity Transmission Congestion Contracts $8 Discounted Cash Flow Discount to adjust auction prices for inter-zonal forward price curves (b) 40.8%-57.9% Discount to adjust auction prices for historical monthly realized settlements (b) 37.5%-82.2% (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 as of September 30, 2015 and 2014 and classified as Level 3 in the fair value hierarchy: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance as of July 1, $13 $27 $11 $14 Included in earnings (4) (8) (1) (3) Included in regulatory assets and liabilities (1) (4) (1) (4) Purchases 1 3 1 3 Settlements (5) 3 (2) 1 Ending balance as of September 30, $4 $21 $8 $11 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance as of January 1, $20 $9 $13 $6 Included in earnings (18) 41 (5) 6 Included in regulatory assets and liabilities (1) 4 (1) 4 Purchases 9 15 5 13 Settlements (6) (48) (4) (18) Ending balance as of September 30, $4 $21 $8 $11 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. 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 for both periods) and purchased power costs ( $3 million loss and $5 million loss ) on the consolidated income statement for the three months ended September 30, 2015 and 2014 , respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ( immaterial for both periods) and purchased power costs ( $12 million loss and $35 million gain ) on the consolidated income statement for the nine months ended September 30, 2015 and 2014 , respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at September 30, 2015 and 2014 is included in non-utility revenues ( immaterial for both periods) and purchased power costs ( $3 million loss and $2 million loss ) on the consolidated income statement for the three months ended September 30, 2015 and 2014 , respectively. For the nine months ended September 30, 2015 and 2014 , the change in fair value relating to Level 3 commodity derivative assets and liabilities is included in non-utility revenues ( immaterial for both periods) and purchased power costs ( $8 million loss and $8 million gain ) on the consolidated income statement, respectively.
CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements	Fair Value Measurements The accounting rules for fair value measurements and disclosures define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. The accounting rules for fair value measurements and disclosures established a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows: • Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange. • Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models. • Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value. Assets and liabilities measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 are summarized below. 2015 2014 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $1 $15 $11 $6 $33 $3 $78 $28 $(27) $82 Commodity held for sale (f) — 37 — (37) — — — — — — Other (a)(b)(d) 181 112 — — 293 163 116 — — 279 Total assets $182 $164 $11 $(31) $326 $166 $194 $28 $(27) $361 Derivative liabilities: Commodity (a)(b)(c) $12 $80 $1 $(50) $43 $18 $246 $8 $(194) $78 Commodity held for sale (f) 2 99 6 (38) 69 — — — — — Total liabilities $14 $179 $7 $(88) $112 $18 $246 $8 $(194) $78 CECONY Derivative assets: Commodity (a)(b)(c) $1 $7 $8 $10 $26 $1 $3 $13 $21 $38 Other (a)(b)(d) 167 104 — — 271 155 106 — — 261 Total assets $168 $111 $8 $10 $297 $156 $109 $13 $21 $299 Derivative liabilities: Commodity (a)(b)(c) $11 $67 $— $(45) $33 $16 $91 $— $(49) $58 (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 nine months ended September 30, 2015 and for the year ended December 31, 2014 . (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2015 and December 31, 2014 , the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties. (f) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet (see Note O). 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 September 30, 2015 Valuation Techniques Unobservable Inputs Range (Millions of Dollars) Con Edison – Commodity Electricity $(5) Discounted Cash Flow Forward energy prices (a) $18.50-$91.75 per MWH Discounted Cash Flow Forward capacity prices (a) $2.96-$15.01 per kW-month Transmission Congestion Contracts/Financial Transmission Rights 9 Discounted Cash Flow Discount to adjust auction prices for inter-zonal forward price curves (b) 40.8%-57.9% Discount to adjust auction prices for historical monthly realized settlements (b) 37.5%-82.2% Inter-zonal forward price curves adjusted for historical zonal losses (b) $(5.30)-$2.94 per MWH Total Con Edison—Commodity $4 CECONY—Commodity Transmission Congestion Contracts $8 Discounted Cash Flow Discount to adjust auction prices for inter-zonal forward price curves (b) 40.8%-57.9% Discount to adjust auction prices for historical monthly realized settlements (b) 37.5%-82.2% (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 as of September 30, 2015 and 2014 and classified as Level 3 in the fair value hierarchy: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance as of July 1, $13 $27 $11 $14 Included in earnings (4) (8) (1) (3) Included in regulatory assets and liabilities (1) (4) (1) (4) Purchases 1 3 1 3 Settlements (5) 3 (2) 1 Ending balance as of September 30, $4 $21 $8 $11 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance as of January 1, $20 $9 $13 $6 Included in earnings (18) 41 (5) 6 Included in regulatory assets and liabilities (1) 4 (1) 4 Purchases 9 15 5 13 Settlements (6) (48) (4) (18) Ending balance as of September 30, $4 $21 $8 $11 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. 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 for both periods) and purchased power costs ( $3 million loss and $5 million loss ) on the consolidated income statement for the three months ended September 30, 2015 and 2014 , respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ( immaterial for both periods) and purchased power costs ( $12 million loss and $35 million gain ) on the consolidated income statement for the nine months ended September 30, 2015 and 2014 , respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at September 30, 2015 and 2014 is included in non-utility revenues ( immaterial for both periods) and purchased power costs ( $3 million loss and $2 million loss ) on the consolidated income statement for the three months ended September 30, 2015 and 2014 , respectively. For the nine months ended September 30, 2015 and 2014 , the change in fair value relating to Level 3 commodity derivative assets and liabilities is included in non-utility revenues ( immaterial for both periods) and purchased power costs ( $8 million loss and $8 million gain ) on the consolidated income statement, respectively.

Variable Interest Entities

Variable Interest Entities	9 Months Ended
	Sep. 30, 2015
Schedule of Equity Method Investments [Line Items]
Variable Interest Entities	Variable Interest Entities 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 has a variable interest in a non-consolidated variable interest entity (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 because CECONY does not have the power to direct activities that it deems most significant to 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. The payments pursuant to these agreements, which constitute CECONY’s maximum exposure to loss with respect to the potential VIEs, for the three months ended September 30, 2015 were $255 million for Cogen Technologies Linden Venture, LP, $83 million for Brooklyn Navy Yard Cogeneration Partners, LP and $25 million for Indeck Energy Services of Corinth, Inc. In September 2015, Con Edison Development purchased a 50 percent membership interest in Panoche Holdings, LLC (Panoche Valley). As a result, Con Edison has a variable interest in Panoche Valley, which is a non-consolidated entity. Panoche Valley owns a project company that is developing a 247 MW (AC) solar electric production project in California. Electricity generated by the project is to be sold to the Southern California Edison Company pursuant to a long-term power purchase agreement. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of Panoche Valley is shared equally between Con Edison Development and a third party. At September 30, 2015 , Con Edison’s consolidated balance sheet includes $33 million in investments and $25 million representing a note receivable related to Panoche Valley, which assessed in accordance with the accounting rules for variable interest entities, is Con Edison’s current maximum exposure to loss in the entity. The following table summarizes the VIEs in which Con Edison Development has entered into as of September 30, 2015 : Project Name (a) Generating Capacity (b) (MWs AC) Power Purchase Agreement Term in Years Year of Initial Investment Location Maximum Exposure to Loss ( Millions of Dollars ) (c) Copper Mountain Solar 3 128 20 2014 Nevada $189 Mesquite Solar 1 83 20 2013 Arizona 108 Copper Mountain Solar 2 75 25 2013 Nevada 85 California Solar 55 25 2012 California 76 Panoche Valley 124 20 2015 California 58 Broken Bow II 37 25 2014 Nebraska 55 Texas Solar 4 32 25 2014 Texas 49 Pilesgrove 9 n/a (d) 2010 New Jersey 26 (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. The maximum exposure for Texas Solar 4 is the net assets of the investment offset by a $9 million noncontrolling interest. (b) Represents Con Edison Development’s ownership interest in the project. (c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet and any related receivables due from the project. For consolidated investments, maximum exposure is equal to the net assets of the investment on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Pilesgrove has 3 - 5 year Solar Renewable Energy Credit hedges in place.
CECONY
Schedule of Equity Method Investments [Line Items]
Variable Interest Entities	Variable Interest Entities 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 has a variable interest in a non-consolidated variable interest entity (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 because CECONY does not have the power to direct activities that it deems most significant to 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. The payments pursuant to these agreements, which constitute CECONY’s maximum exposure to loss with respect to the potential VIEs, for the three months ended September 30, 2015 were $255 million for Cogen Technologies Linden Venture, LP, $83 million for Brooklyn Navy Yard Cogeneration Partners, LP and $25 million for Indeck Energy Services of Corinth, Inc. In September 2015, Con Edison Development purchased a 50 percent membership interest in Panoche Holdings, LLC (Panoche Valley). As a result, Con Edison has a variable interest in Panoche Valley, which is a non-consolidated entity. Panoche Valley owns a project company that is developing a 247 MW (AC) solar electric production project in California. Electricity generated by the project is to be sold to the Southern California Edison Company pursuant to a long-term power purchase agreement. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of Panoche Valley is shared equally between Con Edison Development and a third party. At September 30, 2015 , Con Edison’s consolidated balance sheet includes $33 million in investments and $25 million representing a note receivable related to Panoche Valley, which assessed in accordance with the accounting rules for variable interest entities, is Con Edison’s current maximum exposure to loss in the entity. The following table summarizes the VIEs in which Con Edison Development has entered into as of September 30, 2015 : Project Name (a) Generating Capacity (b) (MWs AC) Power Purchase Agreement Term in Years Year of Initial Investment Location Maximum Exposure to Loss ( Millions of Dollars ) (c) Copper Mountain Solar 3 128 20 2014 Nevada $189 Mesquite Solar 1 83 20 2013 Arizona 108 Copper Mountain Solar 2 75 25 2013 Nevada 85 California Solar 55 25 2012 California 76 Panoche Valley 124 20 2015 California 58 Broken Bow II 37 25 2014 Nebraska 55 Texas Solar 4 32 25 2014 Texas 49 Pilesgrove 9 n/a (d) 2010 New Jersey 26 (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. The maximum exposure for Texas Solar 4 is the net assets of the investment offset by a $9 million noncontrolling interest. (b) Represents Con Edison Development’s ownership interest in the project. (c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet and any related receivables due from the project. For consolidated investments, maximum exposure is equal to the net assets of the investment on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Pilesgrove has 3 - 5 year Solar Renewable Energy Credit hedges in place.

New Financial Accounting Standa

New Financial Accounting Standards	9 Months Ended
	Sep. 30, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Financial Accounting Standards	New Financial Accounting Standards In May 2014, the Financial Accounting Standards Board (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 Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (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. In August 2015, the FASB issued amendments to defer the effective date of ASU No. 2014-09 to reporting periods beginning after December 15, 2017 through ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date”. Early adoption is permitted for reporting 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 January 2015, the FASB issued amendments on income statement guidance through ASU No. 2015-01, “Income Statement—Extraordinary and Unusual Items (Subtopic 225-20).” The amendments eliminate from GAAP the concept of extraordinary items. The amendments are effective for reporting periods beginning after December 15, 2015. Early adoption is permitted provided that the guidance is applied from the beginning of the fiscal year of adoption. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In February 2015, the FASB issued amendments on consolidation guidance through ASU No. 2015-02, “Consolidation (Topic 810).” The amendments provide additional guidance for VIE accounting of limited partnerships and similar legal entities, fees paid to decision makers of a VIE, the effect of fee arrangements on primary beneficiary determination, and the effect of related parties on primary beneficiary determination. The amendments are effective prospectively for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In April 2015, the FASB issued amendments on debt issuance costs guidance through ASU No. 2015-03, “Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs.” The amendments provide additional guidance requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a reduction of that debt liability rather than as a deferred cost (i.e. an asset) as required by current guidance. The FASB further clarified debt issuance cost guidance in August 2015 through ASU 2015-15, “Presentation and Subsequent Measurement of Debt Issuance Costs Associated With Line-of-Credit Arrangements,” which allows entities to continue presenting debt issuance costs related to line-of-credit arrangements as deferred costs on the balance sheet. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In April 2015, the FASB issued amendments on internal-use software guidance through ASU No. 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement.” The amendments provide guidance to customers about whether a cloud computing arrangement should be accounted for as a license of internal use software or as a service contract. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In May 2015, the FASB issued amendments on disclosure guidance for investments using Net Asset Value per Share through ASU No. 2015-07, “Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent).” The amendments remove the requirement to categorize investments in the fair value hierarchy if Net Asset Value per Share is used as a practical expedient to determine the fair value of the investment. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In July 2015, the FASB issued amendments on the measurement of first-in, first-out and average cost inventory through ASU No.2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory.” The amendments require that inventory within the scope of the guidance be measured at the lower of cost and net realizable value rather than cost and market value. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2016. Early adoption is permitted. 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 2015, the FASB issued amendments on the accounting for derivative contracts through ASU No.2015-13, “Derivatives and Hedging (Topic 815): Application of the Normal Purchases and Normal Sales Scope Exception to Certain Electricity Contracts within Nodal Energy Markets.” The amendments specify that the use of locational marginal pricing by an independent system operator does not constitute a net settlement of a contract and would not cause the contract to fail the physical delivery criterion of the normal purchases and normal sales scope exception. The amendments are effective upon issuance and should be applied prospectively. The application of this guidance does not have a material impact on the Companies' financial position, results of operations and liquidity. In September 2015, the FASB issued an amendment to guidance for business combinations through ASU No. 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments.” The amendment requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined as opposed to recognizing retrospectively. The amendment also requires that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. For public entities, the amendment is effective prospectively for reporting periods beginning after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
CECONY
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Financial Accounting Standards	New Financial Accounting Standards In May 2014, the Financial Accounting Standards Board (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 Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (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. In August 2015, the FASB issued amendments to defer the effective date of ASU No. 2014-09 to reporting periods beginning after December 15, 2017 through ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date”. Early adoption is permitted for reporting 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 January 2015, the FASB issued amendments on income statement guidance through ASU No. 2015-01, “Income Statement—Extraordinary and Unusual Items (Subtopic 225-20).” The amendments eliminate from GAAP the concept of extraordinary items. The amendments are effective for reporting periods beginning after December 15, 2015. Early adoption is permitted provided that the guidance is applied from the beginning of the fiscal year of adoption. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In February 2015, the FASB issued amendments on consolidation guidance through ASU No. 2015-02, “Consolidation (Topic 810).” The amendments provide additional guidance for VIE accounting of limited partnerships and similar legal entities, fees paid to decision makers of a VIE, the effect of fee arrangements on primary beneficiary determination, and the effect of related parties on primary beneficiary determination. The amendments are effective prospectively for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In April 2015, the FASB issued amendments on debt issuance costs guidance through ASU No. 2015-03, “Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs.” The amendments provide additional guidance requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a reduction of that debt liability rather than as a deferred cost (i.e. an asset) as required by current guidance. The FASB further clarified debt issuance cost guidance in August 2015 through ASU 2015-15, “Presentation and Subsequent Measurement of Debt Issuance Costs Associated With Line-of-Credit Arrangements,” which allows entities to continue presenting debt issuance costs related to line-of-credit arrangements as deferred costs on the balance sheet. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In April 2015, the FASB issued amendments on internal-use software guidance through ASU No. 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement.” The amendments provide guidance to customers about whether a cloud computing arrangement should be accounted for as a license of internal use software or as a service contract. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In May 2015, the FASB issued amendments on disclosure guidance for investments using Net Asset Value per Share through ASU No. 2015-07, “Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent).” The amendments remove the requirement to categorize investments in the fair value hierarchy if Net Asset Value per Share is used as a practical expedient to determine the fair value of the investment. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In July 2015, the FASB issued amendments on the measurement of first-in, first-out and average cost inventory through ASU No.2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory.” The amendments require that inventory within the scope of the guidance be measured at the lower of cost and net realizable value rather than cost and market value. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2016. Early adoption is permitted. 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 2015, the FASB issued amendments on the accounting for derivative contracts through ASU No.2015-13, “Derivatives and Hedging (Topic 815): Application of the Normal Purchases and Normal Sales Scope Exception to Certain Electricity Contracts within Nodal Energy Markets.” The amendments specify that the use of locational marginal pricing by an independent system operator does not constitute a net settlement of a contract and would not cause the contract to fail the physical delivery criterion of the normal purchases and normal sales scope exception. The amendments are effective upon issuance and should be applied prospectively. The application of this guidance does not have a material impact on the Companies' financial position, results of operations and liquidity. In September 2015, the FASB issued an amendment to guidance for business combinations through ASU No. 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments.” The amendment requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined as opposed to recognizing retrospectively. The amendment also requires that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. For public entities, the amendment is effective prospectively for reporting periods beginning after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

Assets Held For Sale

Assets Held For Sale	9 Months Ended
	Sep. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Assets Held For Sale	Assets Held For Sale In June 2015, upon evaluating strategic alternatives, Con Edison initiated a plan to actively market and sell the retail electric supply business of its competitive energy businesses. The company expects the sale to close within the next twelve months. The company classified as held for sale the related assets and liabilities and ceased recording depreciation expense on these assets. There was no impairment of the assets held for sale, as the estimated fair value less costs to sell exceeded the carrying amount. In October 2015, upon evaluating strategic alternatives, O&R entered into an agreement to sell Pike County Light & Power Company (Pike) to Corning Natural Gas Holding Corporation for $16 million , including estimated working capital adjustments. The closing of the sale, which the company expects to occur within the next twelve months, is subject to certain regulatory approvals by the NYSPSC, FERC and Pennsylvania Public Utility Commission. At September 30, 2015, the company classified the related electric and gas assets and liabilities as held for sale and ceased recording depreciation expense on these assets. O&R recorded an impairment charge of $5 million ( $3 million net of taxes), representing the difference between the carrying amount of Pike’s assets and the estimated sales proceeds. The impairment is reported in other deductions on Con Edison's consolidated income statement for the three and nine months ended September 30, 2015 and reflected in the amount included in assets held for sale on the company's consolidated balance sheet at September 30, 2015 . At September 30, 2015 , the carrying amounts of the assets and liabilities designated as held for sale were as follows: (Millions of Dollars) Retail Electric Supply Business Pike Total Cash and temporary cash investments $— $2 $2 Accounts receivable 89 — 89 Accrued unbilled revenue 78 — 78 Other assets 2 1 3 Total current assets 169 3 172 Utility plant, less accumulated depreciation of $6 — 14 14 Non-utility property, less accumulated depreciation of $13 4 — 4 Regulatory assets — 4 4 Total assets held for sale $173 $21 $194 Derivative liabilities $47 $— $47 Accounts payable 6 — 6 Other 2 1 3 Total current liabilities 55 1 56 Derivative liabilities 22 — 22 Long-term debt — 3 3 Other deferred credits and noncurrent liabilities — 1 1 Total liabilities held for sale $77 $5 $82

Summary of Significant Accoun24

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2015
Accounting Policies [Abstract]
New Financial Accounting Standards	New Financial Accounting Standards In May 2014, the Financial Accounting Standards Board (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 Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (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. In August 2015, the FASB issued amendments to defer the effective date of ASU No. 2014-09 to reporting periods beginning after December 15, 2017 through ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date”. Early adoption is permitted for reporting 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 January 2015, the FASB issued amendments on income statement guidance through ASU No. 2015-01, “Income Statement—Extraordinary and Unusual Items (Subtopic 225-20).” The amendments eliminate from GAAP the concept of extraordinary items. The amendments are effective for reporting periods beginning after December 15, 2015. Early adoption is permitted provided that the guidance is applied from the beginning of the fiscal year of adoption. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In February 2015, the FASB issued amendments on consolidation guidance through ASU No. 2015-02, “Consolidation (Topic 810).” The amendments provide additional guidance for VIE accounting of limited partnerships and similar legal entities, fees paid to decision makers of a VIE, the effect of fee arrangements on primary beneficiary determination, and the effect of related parties on primary beneficiary determination. The amendments are effective prospectively for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In April 2015, the FASB issued amendments on debt issuance costs guidance through ASU No. 2015-03, “Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs.” The amendments provide additional guidance requiring that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a reduction of that debt liability rather than as a deferred cost (i.e. an asset) as required by current guidance. The FASB further clarified debt issuance cost guidance in August 2015 through ASU 2015-15, “Presentation and Subsequent Measurement of Debt Issuance Costs Associated With Line-of-Credit Arrangements,” which allows entities to continue presenting debt issuance costs related to line-of-credit arrangements as deferred costs on the balance sheet. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In April 2015, the FASB issued amendments on internal-use software guidance through ASU No. 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement.” The amendments provide guidance to customers about whether a cloud computing arrangement should be accounted for as a license of internal use software or as a service contract. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In May 2015, the FASB issued amendments on disclosure guidance for investments using Net Asset Value per Share through ASU No. 2015-07, “Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent).” The amendments remove the requirement to categorize investments in the fair value hierarchy if Net Asset Value per Share is used as a practical expedient to determine the fair value of the investment. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In July 2015, the FASB issued amendments on the measurement of first-in, first-out and average cost inventory through ASU No.2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory.” The amendments require that inventory within the scope of the guidance be measured at the lower of cost and net realizable value rather than cost and market value. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2016. Early adoption is permitted. 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 2015, the FASB issued amendments on the accounting for derivative contracts through ASU No.2015-13, “Derivatives and Hedging (Topic 815): Application of the Normal Purchases and Normal Sales Scope Exception to Certain Electricity Contracts within Nodal Energy Markets.” The amendments specify that the use of locational marginal pricing by an independent system operator does not constitute a net settlement of a contract and would not cause the contract to fail the physical delivery criterion of the normal purchases and normal sales scope exception. The amendments are effective upon issuance and should be applied prospectively. The application of this guidance does not have a material impact on the Companies' financial position, results of operations and liquidity. In September 2015, the FASB issued an amendment to guidance for business combinations through ASU No. 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments.” The amendment requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined as opposed to recognizing retrospectively. The amendment also requires that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. For public entities, the amendment is effective prospectively for reporting periods beginning after December 15, 2015. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

Summary of Significant Accoun25

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2015
Accounting Policies [Abstract]
Earnings Per Common Share	For the three and nine months ended September 30, 2015 and 2014 , basic and diluted earnings per share (EPS) for Con Edison are calculated as follows: For the Three Months Ended September 30, For the Nine Months Ended September 30, (Millions of Dollars, except per share amounts/Shares in Millions) 2015 2014 2015 2014 Net income for common stock $428 $436 $1,017 $1,010 Weighted average common shares outstanding – basic 292.9 292.9 292.9 292.9 Add: Incremental shares attributable to effect of potentially dilutive securities 1.3 1.1 1.3 1.1 Adjusted weighted average common shares outstanding – diluted 294.2 294.0 294.2 294.0 Net Income for common stock per common share – basic $1.46 $1.49 $3.47 $3.45 Net Income for common stock per common share – diluted $1.45 $1.48 $3.46 $3.44
Changes in Accumulated Other Comprehensive Income/(Loss) by Component	For the three and nine months ended September 30, 2015 and 2014 , changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance, accumulated OCI, net of taxes (a) $(39) $(20) $(10) $(5) Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2015 and 2014 (a)(b) 1 1 1 — Current period OCI, net of taxes 1 1 1 — Ending balance, accumulated OCI, net of taxes $(38) $(19) $(9) $(5) For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance, accumulated OCI, net of taxes (a) $(45) $(25) $(11) $(6) OCI before reclassifications, net of tax of $(2) and $(1) for Con Edison in 2015 and 2014, respectively 3 2 — — Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(3) for Con Edison in 2015 and 2014 (a)(b) 4 4 2 1 Current period OCI, net of taxes 7 6 2 1 Ending balance, accumulated OCI, net of taxes $(38) $(19) $(9) $(5) (a) Tax reclassified from accumulated OCI is reported in the income tax expense line item of the income statement. (b) 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 total periodic pension and other postretirement benefit cost. See Notes E and F.

Regulatory Matters (Tables)

Regulatory Matters (Tables)	9 Months Ended
	Sep. 30, 2015
Public Utilities, General Disclosures [Line Items]
Regulatory Assets and Liabilities	Regulatory assets and liabilities at September 30, 2015 and December 31, 2014 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Regulatory assets Unrecognized pension and other postretirement costs $4,208 $4,846 $4,008 $4,609 Future income tax 2,363 2,273 2,254 2,166 Environmental remediation costs 884 925 784 820 Revenue taxes 235 219 223 208 Deferred storm costs 218 319 137 224 Surcharge for New York State assessment 68 99 63 92 Unamortized loss on reacquired debt 52 57 50 55 Pension and other postretirement benefits deferrals 49 66 21 42 Net electric deferrals 49 63 49 63 O&R property tax reconciliation 45 36 — — Deferred derivative losses 32 25 28 23 Preferred stock redemption 26 27 26 27 O&R transition bond charges 22 27 — — Workers’ compensation 11 8 11 8 Recoverable energy costs 4 19 4 17 Other 179 147 162 127 Regulatory assets – noncurrent 8,445 9,156 7,820 8,481 Deferred derivative losses 57 97 52 92 Future income tax 9 10 — — Recoverable energy costs 1 41 1 40 Regulatory assets – current 67 148 53 132 Total Regulatory Assets $8,512 $9,304 $7,873 $8,613 Regulatory liabilities Allowance for cost of removal less salvage $633 $598 $530 $499 Property tax reconciliation 299 295 299 295 Base rate change deferrals 134 155 134 155 Net unbilled revenue deferrals 134 138 134 138 Prudence proceeding 100 105 100 105 Pension and other postretirement benefit deferrals 76 46 46 37 Variable-rate tax-exempt debt – cost rate reconciliation 75 78 64 78 New York State income tax rate change 67 62 63 59 Property tax refunds 55 87 55 87 Carrying charges on repair allowance and bonus depreciation 50 58 49 57 Earnings sharing – electric and steam 37 19 37 18 Net utility plant reconciliations 31 21 31 20 World Trade Center settlement proceeds 26 41 26 41 Unrecognized other postretirement costs 20 — 20 — Other 203 290 167 248 Regulatory liabilities – noncurrent 1,940 1,993 1,755 1,837 Refundable energy costs 99 128 71 84 Revenue decoupling mechanism 41 30 39 30 Future income tax 20 24 20 24 Deferred derivative gains 5 5 5 4 Regulatory liabilities – current 165 187 135 142 Total Regulatory Liabilities $2,105 $2,180 $1,890 $1,979
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Summary of Rate Plan	The following table contains a summary of the rate plan for 2016: Effective period January 2016 – December 2016 Base rate changes None (a) Amortizations to income of net regulatory (assets) and liabilities Additional $123 million of net regulatory liabilities (b). Other revenue sources Continued retention of $90 million of annual transmission congestion revenues. Revenue decoupling mechanism Continued reconciliation of actual electric delivery revenues to those authorized in the rate plan. Recoverable energy costs Continued current rate recovery of purchased power and fuel costs (c). Negative revenue adjustments Continued potential penalties (up to $400 million annually) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support, the impact of new laws and environmental remediation to amounts reflected in rates (d). Net utility plant reconciliations Target levels reflected in rates are as follows: Average rate base $18,282 million Weighted average cost of capital (after-tax) 6.91 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. Cost of long-term debt 5.09 percent Common equity ratio 48 percent (a) The impact of 2014 and 2015 base rate changes under the current electric rate plan will continue to be deferred. $249 million of annual revenues collected from electric customers will continue to be subject to potential refund following NYSPSC staff review of certain costs. Revenues will continue to include $21 million as funding for major storm reserve. (b) Annual amortization of $107 million of the regulatory asset for deferred Superstorm Sandy and other major storm costs will continue. The costs recoverable from customers will be reduced by $4 million . The costs will no longer be subject to NYSPSC staff review and the recovery of the costs will no longer be subject to refund. (c) For transmission service provided pursuant to the open access transmission tariff of PJM Interconnection LLC (PJM), 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 the Federal Energy Regulatory Commission (FERC) a request that would substantially increase the charges for the transmission service. FERC has granted the request and rejected CECONY’s protests. CECONY is challenging the FERC’s decision. In August 2015, PJM submitted a request to FERC that, if approved by FERC, would further increase the charges. In September 2015, CECONY filed a protest to this increase. (d) Deferrals for property taxes will continue to be limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity. In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral of 30 percent of the amount reflected in rates.
O&R | Electric
Public Utilities, General Disclosures [Line Items]
Summary of Rate Plan	The following tables contain a summary of the new rate plans: O&R New York - Electric Effective period November 2015 - October 2017 Base rate changes Yr. 1 - $9.3 million Amortizations to income of net regulatory (assets) and liabilities (a) Yr. 1 - $(8.5) million Revenue decoupling mechanism Continued reconciliation of actual electric delivery revenues to those authorized in the rate plan. Recoverable energy costs Continued current rate recovery of purchased power costs. Negative revenue adjustments Potential penalties (up to $4 million annually) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, major storms, property taxes, the impact of new laws and environmental remediation to amounts reflected in rates. Net utility plant reconciliations (b) Target levels reflected in rates are: Average rate base Yr. 1 - $763 million Weighted average cost of capital (after-tax) Yr. 1 - 7.10 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. Cost of long-term debt Yr. 1 - 5.42 percent Common equity ratio 48 percent (a) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a five-year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015. (b) Excludes electric advanced metering infrastructure as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Summary of Rate Plan	O&R New York - Gas Effective period November 2015 - October 2018 Base rate changes Yr. 1 - $16.4 million Amortizations to income of net regulatory (assets) and liabilities (a) Yr. 1 - $(1.7) million Revenue decoupling mechanism Continued reconciliation of actual gas delivery revenues to those authorized in the rate plan, including through weather normalization clause. Recoverable energy costs Continued current rate recovery of purchased gas costs. Negative revenue adjustments Potential penalties (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $5.8 million in Yr. 3) if certain performance targets are not met. Cost reconciliations Continued reconciliation of expenses for pension and other postretirement benefits, property taxes, the impact of new laws and environmental remediation to amounts reflected in rates. Net utility plant reconciliations (b) Target levels reflected in rates are: Average rate base Yr. 1 - $366 million Weighted average cost of capital (after-tax) Yr. 1 - 7.10 percent Authorized return on common equity 9.0 percent Earnings sharing Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. Cost of long-term debt Yr. 1 - 5.42 percent Common equity ratio 48 percent (a) Reflects that the company will not recover from customers a total of approximately $14 million of regulatory assets for property tax and interest rate reconciliations. Amounts that will not be recovered from customers were charged-off in June 2015. (b) Excludes gas advanced metering infrastructure as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $0.5 million in year 1, $4.2 million in year 2 and $7.2 million in year 3.

Capitalization (Tables)

Capitalization (Tables)	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Carrying Amounts and Fair Values of Long-Term Debt	The carrying amounts and fair values of long-term debt at September 30, 2015 and December 31, 2014 are: (Millions of Dollars) 2015 2014 Long-Term Debt (including current portion) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $12,282 $13,575 $12,191 $13,998 CECONY $11,215 $12,385 $11,214 $12,846

Pension Benefits (Tables)

Pension Benefits (Tables)	9 Months Ended
	Sep. 30, 2015
Pension Benefits
Total Periodic Benefit Costs	The components of the Companies’ total periodic benefit costs for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost – including administrative expenses $74 $57 $70 $53 Interest cost on projected benefit obligation 144 143 135 134 Expected return on plan assets (222) (208) (210) (198) Recognition of net actuarial loss 194 154 183 146 Recognition of prior service costs 1 1 — 1 NET PERIODIC BENEFIT COST $191 $147 $178 $136 Amortization of regulatory asset 1 1 1 1 TOTAL PERIODIC BENEFIT COST $192 $148 $179 $137 Cost capitalized (80) (57) (76) (54) Reconciliation to rate level (14) 30 (14) 28 Cost charged to operating expenses $98 $121 $89 $111 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost – including administrative expenses $223 $170 $209 $158 Interest cost on projected benefit obligation 431 429 404 402 Expected return on plan assets (664) (624) (630) (592) Recognition of net actuarial loss 581 464 550 439 Recognition of prior service costs 3 3 1 2 NET PERIODIC BENEFIT COST $574 $442 $534 $409 Amortization of regulatory asset 2 2 2 2 TOTAL PERIODIC BENEFIT COST $576 $444 $536 $411 Cost capitalized (224) (166) (214) (156) Reconciliation to rate level (56) 86 (56) 78 Cost charged to operating expenses $296 $364 $266 $333

Other Postretirement Benefits (

Other Postretirement Benefits (Tables)	9 Months Ended
	Sep. 30, 2015
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total Periodic Benefit Costs	The components of the Companies’ total periodic other postretirement benefit costs for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost $5 $5 $4 $4 Interest cost on accumulated other postretirement benefit obligation 13 15 11 13 Expected return on plan assets (20) (19) (17) (17) Recognition of net actuarial loss 8 14 7 13 Recognition of prior service cost (5) (5) (4) (4) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST $1 $10 $1 $9 Cost capitalized (1) (4) (1) (4) Reconciliation to rate level 4 3 2 1 Cost charged to operating expenses $4 $9 $2 $6 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Service cost $15 $14 $11 $11 Interest cost on accumulated other postretirement benefit obligation 38 45 32 39 Expected return on plan assets (59) (58) (51) (51) Recognition of net actuarial loss 24 43 21 38 Recognition of prior service cost (15) (14) (10) (11) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST $3 $30 $3 $26 Cost capitalized (2) (11) (2) (10) Reconciliation to rate level 12 8 5 2 Cost charged to operating expenses $13 $27 $6 $18

Environmental Matters (Tables)

Environmental Matters (Tables)	9 Months Ended
	Sep. 30, 2015
Environmental Remediation Obligations [Abstract]
Accrued Liabilities and Regulatory Assets	The accrued liabilities and regulatory assets related to Superfund Sites at September 30, 2015 and December 31, 2014 were as follows: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Accrued Liabilities: Manufactured gas plant sites $666 $684 $572 $587 Other Superfund Sites 80 80 79 79 Total $746 $764 $651 $666 Regulatory assets $884 $925 $784 $820
Environmental Remediation Costs	Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites for the three and nine months ended September 30, 2015 and 2014 were as follows: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Remediation costs incurred $6 $5 $6 $2 Insurance recoveries received — — — — For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Remediation costs incurred $21 $19 $18 $12 Insurance recoveries received (a) — 5 — 5 (a) 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 September 30, 2015 and December 31, 2014 were as follows: Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $86 $83 $81 $78 Regulatory assets – workers’ compensation $11 $8 $11 $8

Other Material Contingencies (T

Other Material Contingencies (Tables)	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Total Guarantees	A summary, by type and term, of Con Edison’s total guarantees at September 30, 2015 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) NY Transco $946 $413 $— $1,359 Energy transactions 760 36 89 885 Renewable electric production projects 176 82 44 302 Other 30 — — 30 Total $1,912 $531 $133 $2,576

Financial Information by Busi32

Financial Information by Business Segment (Tables)	9 Months Ended
	Sep. 30, 2015
Segment Reporting [Abstract]
Financial Data for Business Segments	The financial data for the business segments are as follows: For the Three Months Ended September 30, Operating revenues Inter-segment revenues Depreciation and amortization Operating income (Millions of Dollars) 2015 2014 2015 2014 2015 2014 2015 2014 CECONY Electric $2,558 $2,582 $4 $4 $207 $198 $811 $811 Gas 213 210 1 1 35 33 (17) (14) Steam 58 46 22 21 20 19 (49) (41) Consolidation adjustments — — (27) (26) — — — — Total CECONY $2,829 $2,838 $— $— $262 $250 $745 $756 O&R Electric $205 $205 $— $— $13 $12 $51 $51 Gas 24 27 — — 4 4 (9) (8) Total O&R $229 $232 $— $— $17 $16 $42 $43 Competitive energy businesses $386 $321 $(2) $(3) $6 $3 $43 $20 Other (a) (1) (1) 2 3 — 1 — — Total Con Edison $3,443 $3,390 $— $— $285 $270 $830 $819 (a) Parent company and consolidation adjustments. Other does not represent a business segment. For the Nine Months Ended September 30, Operating revenues Inter-segment revenues Depreciation and amortization Operating income (Millions of Dollars) 2015 2014 2015 2014 2015 2014 2015 2014 CECONY Electric $6,416 $6,635 $13 $12 $610 $581 $1,511 $1,416 Gas 1,177 1,359 4 4 105 98 278 273 Steam 529 485 65 62 58 58 100 97 Consolidation adjustments — — (82) (78) — — — — Total CECONY $8,122 $8,479 $— $— $773 $737 $1,889 $1,786 O&R Electric $523 $525 $— $— $38 $33 $85 $87 Gas 117 155 — — 13 12 — 15 Total O&R $640 $680 $— $— $51 $45 $85 $102 Competitive energy businesses $1,087 $934 $(5) $(2) $16 $14 $53 $70 Other (a) (2) (2) 5 2 — — 1 1 Total Con Edison $9,847 $10,091 $— $— $840 $796 $2,028 $1,959 (a) Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and He33

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair Values of Commodity Derivatives Including Offsetting Assets	The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at September 30, 2015 and December 31, 2014 were: (Millions of Dollars) 2015 2014 Balance Sheet Location Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Con Edison Fair value of derivative assets Current $47 $(33) $14 (b) $111 $(67) $44 (b) Current - assets held for sale (c) 39 (39) — — — — Noncurrent 19 (17) 2 34 (23) 11 Total fair value of derivative assets $105 $(89) $16 $145 $(90) $55 Fair value of derivative liabilities Current $(84) $58 $(26) $(242) $139 $(103) Current - liabilities held for sale (c) (77) 30 (47) — — — Noncurrent (48) 31 (17) (66) 91 25 Noncurrent - liabilities held for sale (c) (31) 9 (22) — — — Total fair value of derivative liabilities $(240) $128 $(112) $(308) $230 $(78) Net fair value derivative assets/(liabilities) $(135) $39 $(96) (b) $(163) $140 $(23) (b) CECONY Fair value of derivative assets Current $36 $(28) $8 (b) $26 $(15) $11 (b) Noncurrent 16 (15) 1 22 (20) 2 Total fair value of derivative assets $52 $(43) $9 $48 $(35) $13 Fair value of derivative liabilities Current $(72) $53 $(19) $(96) $48 $(48) Noncurrent (42) 28 (14) (42) 32 (10) Total fair value of derivative liabilities $(114) $81 $(33) $(138) $80 $(58) Net fair value derivative assets/(liabilities) $(62) $38 $(24) (b) $(90) $45 $(45) (b) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At September 30, 2015 and December 31, 2014 , margin deposits for Con Edison ( $17 million and $27 million , respectively) and CECONY ( $17 million and $25 million , respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet (see Note O).
Fair Values of Commodity Derivatives Including Offsetting Liabilities	The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at September 30, 2015 and December 31, 2014 were: (Millions of Dollars) 2015 2014 Balance Sheet Location Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Con Edison Fair value of derivative assets Current $47 $(33) $14 (b) $111 $(67) $44 (b) Current - assets held for sale (c) 39 (39) — — — — Noncurrent 19 (17) 2 34 (23) 11 Total fair value of derivative assets $105 $(89) $16 $145 $(90) $55 Fair value of derivative liabilities Current $(84) $58 $(26) $(242) $139 $(103) Current - liabilities held for sale (c) (77) 30 (47) — — — Noncurrent (48) 31 (17) (66) 91 25 Noncurrent - liabilities held for sale (c) (31) 9 (22) — — — Total fair value of derivative liabilities $(240) $128 $(112) $(308) $230 $(78) Net fair value derivative assets/(liabilities) $(135) $39 $(96) (b) $(163) $140 $(23) (b) CECONY Fair value of derivative assets Current $36 $(28) $8 (b) $26 $(15) $11 (b) Noncurrent 16 (15) 1 22 (20) 2 Total fair value of derivative assets $52 $(43) $9 $48 $(35) $13 Fair value of derivative liabilities Current $(72) $53 $(19) $(96) $48 $(48) Noncurrent (42) 28 (14) (42) 32 (10) Total fair value of derivative liabilities $(114) $81 $(33) $(138) $80 $(58) Net fair value derivative assets/(liabilities) $(62) $38 $(24) (b) $(90) $45 $(45) (b) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At September 30, 2015 and December 31, 2014 , margin deposits for Con Edison ( $17 million and $27 million , respectively) and CECONY ( $17 million and $25 million , respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet (see Note O).
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 three and nine months ended September 30, 2015 and 2014 : For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2015 2014 2015 2014 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $(1) $(6) $(1) $(5) Noncurrent Deferred derivative gains — (5) — (5) Total deferred gains/(losses) $(1) $(11) $(1) $(10) Current Deferred derivative losses $8 $(6) $8 $(5) Current Recoverable energy costs (53) (33) (49) (29) Noncurrent Deferred derivative losses 14 3 13 3 Total deferred gains/(losses) $(31) $(36) $(28) $(31) Net deferred gains/(losses) $(32) $(47) $(29) $(41) Income Statement Location Pre-tax gain/(loss) recognized in income Purchased power expense $(31) (a) $(28) (b) $— $— Gas purchased for resale (26) (29) — — Non-utility revenue 5 (a) 20 (b) — — Total pre-tax gain/(loss) recognized in income $(52) $(37) $— $— (a) For the three months ended September 30, 2015 , Con Edison recorded in purchased power expense an unrealized pre-tax gain of $12 million . (b) For the three months ended September 30, 2014 , Con Edison recorded in purchased power expense an unrealized pre-tax loss of $(1) million . For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2015 2014 2015 2014 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $— $25 $1 $20 Noncurrent Deferred derivative gains — 1 — 1 Total deferred gains/(losses) $— $26 $1 $21 Current Deferred derivative losses $40 $10 $40 $10 Current Recoverable energy costs (92) 54 (87) 41 Noncurrent Deferred derivative losses (7) 3 (5) 2 Total deferred gains/(losses) $(59) $67 $(52) $53 Net deferred gains/(losses) $(59) $93 $(51) $74 Income Statement Location Pre-tax gain/(loss) recognized in income Purchased power expense $(60) (a) $134 (b) $— $— Gas purchased for resale (94) (75) — — Non-utility revenue 20 (a) 10 (b) — — Total pre-tax gain/(loss) recognized in income $(134) $69 $— $— (a) For the nine months ended September 30, 2015 , Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ( $3 million loss) and purchased power expense ( $6 million gain). (b) For the nine months ended September 30, 2014 , Con Edison recorded in purchased power expense an unrealized pre-tax gain of $14 million .
Hedged Volume of Derivative Transactions	The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at September 30, 2015 : Electric Energy (MWHs) (a)(b) Capacity (MWs) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison (c) 18,475,688 7,201 63,386,967 4,620,000 CECONY 5,972,325 2,400 56,690,000 4,620,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts which are associated with electric and gas contracts and hedged volumes. (c) Includes 11,445,799 MWHs for electric energy, 5,436 MWs for capacity and 509,294 Dt for natural gas derivative transactions that are held for sale.
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 September 30, 2015 : (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $52 $32 Collateral posted 5 — Additional collateral (b) (downgrade one level from current ratings) 1 — Additional collateral (b) (downgrade to below investment grade from current ratings) 72 (c) 43 (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 the competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $3 million at September 30, 2015 . 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 to offset. (c) Derivative instruments that are net assets have been excluded from the table. At September 30, 2015 , if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $9 million .

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2015
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 as of September 30, 2015 and December 31, 2014 are summarized below. 2015 2014 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $1 $15 $11 $6 $33 $3 $78 $28 $(27) $82 Commodity held for sale (f) — 37 — (37) — — — — — — Other (a)(b)(d) 181 112 — — 293 163 116 — — 279 Total assets $182 $164 $11 $(31) $326 $166 $194 $28 $(27) $361 Derivative liabilities: Commodity (a)(b)(c) $12 $80 $1 $(50) $43 $18 $246 $8 $(194) $78 Commodity held for sale (f) 2 99 6 (38) 69 — — — — — Total liabilities $14 $179 $7 $(88) $112 $18 $246 $8 $(194) $78 CECONY Derivative assets: Commodity (a)(b)(c) $1 $7 $8 $10 $26 $1 $3 $13 $21 $38 Other (a)(b)(d) 167 104 — — 271 155 106 — — 261 Total assets $168 $111 $8 $10 $297 $156 $109 $13 $21 $299 Derivative liabilities: Commodity (a)(b)(c) $11 $67 $— $(45) $33 $16 $91 $— $(49) $58 (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 nine months ended September 30, 2015 and for the year ended December 31, 2014 . (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2015 and December 31, 2014 , the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties. (f) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet (see Note O).
Schedule of Commodity Derivatives	The risk management group reports to the Companies’ Vice President and Treasurer. Fair Value of Level 3 at September 30, 2015 Valuation Techniques Unobservable Inputs Range (Millions of Dollars) Con Edison – Commodity Electricity $(5) Discounted Cash Flow Forward energy prices (a) $18.50-$91.75 per MWH Discounted Cash Flow Forward capacity prices (a) $2.96-$15.01 per kW-month Transmission Congestion Contracts/Financial Transmission Rights 9 Discounted Cash Flow Discount to adjust auction prices for inter-zonal forward price curves (b) 40.8%-57.9% Discount to adjust auction prices for historical monthly realized settlements (b) 37.5%-82.2% Inter-zonal forward price curves adjusted for historical zonal losses (b) $(5.30)-$2.94 per MWH Total Con Edison—Commodity $4 CECONY—Commodity Transmission Congestion Contracts $8 Discounted Cash Flow Discount to adjust auction prices for inter-zonal forward price curves (b) 40.8%-57.9% Discount to adjust auction prices for historical monthly realized settlements (b) 37.5%-82.2% (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 as of September 30, 2015 and 2014 and classified as Level 3 in the fair value hierarchy: For the Three Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance as of July 1, $13 $27 $11 $14 Included in earnings (4) (8) (1) (3) Included in regulatory assets and liabilities (1) (4) (1) (4) Purchases 1 3 1 3 Settlements (5) 3 (2) 1 Ending balance as of September 30, $4 $21 $8 $11 For the Nine Months Ended September 30, Con Edison CECONY (Millions of Dollars) 2015 2014 2015 2014 Beginning balance as of January 1, $20 $9 $13 $6 Included in earnings (18) 41 (5) 6 Included in regulatory assets and liabilities (1) 4 (1) 4 Purchases 9 15 5 13 Settlements (6) (48) (4) (18) Ending balance as of September 30, $4 $21 $8 $11

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	9 Months Ended
	Sep. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Summary of VIEs	The following table summarizes the VIEs in which Con Edison Development has entered into as of September 30, 2015 : Project Name (a) Generating Capacity (b) (MWs AC) Power Purchase Agreement Term in Years Year of Initial Investment Location Maximum Exposure to Loss ( Millions of Dollars ) (c) Copper Mountain Solar 3 128 20 2014 Nevada $189 Mesquite Solar 1 83 20 2013 Arizona 108 Copper Mountain Solar 2 75 25 2013 Nevada 85 California Solar 55 25 2012 California 76 Panoche Valley 124 20 2015 California 58 Broken Bow II 37 25 2014 Nebraska 55 Texas Solar 4 32 25 2014 Texas 49 Pilesgrove 9 n/a (d) 2010 New Jersey 26 (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. The maximum exposure for Texas Solar 4 is the net assets of the investment offset by a $9 million noncontrolling interest. (b) Represents Con Edison Development’s ownership interest in the project. (c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet and any related receivables due from the project. For consolidated investments, maximum exposure is equal to the net assets of the investment on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Pilesgrove has 3 - 5 year Solar Renewable Energy Credit hedges in place.

Assets Held For Sale (Tables)

Assets Held For Sale (Tables)	9 Months Ended
	Sep. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations	At September 30, 2015 , the carrying amounts of the assets and liabilities designated as held for sale were as follows: (Millions of Dollars) Retail Electric Supply Business Pike Total Cash and temporary cash investments $— $2 $2 Accounts receivable 89 — 89 Accrued unbilled revenue 78 — 78 Other assets 2 1 3 Total current assets 169 3 172 Utility plant, less accumulated depreciation of $6 — 14 14 Non-utility property, less accumulated depreciation of $13 4 — 4 Regulatory assets — 4 4 Total assets held for sale $173 $21 $194 Derivative liabilities $47 $— $47 Accounts payable 6 — 6 Other 2 1 3 Total current liabilities 55 1 56 Derivative liabilities 22 — 22 Long-term debt — 3 3 Other deferred credits and noncurrent liabilities — 1 1 Total liabilities held for sale $77 $5 $82

Summary of Significant Accoun37

Summary of Significant Accounting Policies - Earnings Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Sep. 30, 2015	Sep. 30, 2014
Accounting Policies [Abstract]
Net income for common stock	$ 428	$ 219	$ 370	$ 436	$ 212	$ 361	$ 1,017	$ 1,010
Weighted average common shares outstanding – basic	292.9			292.9			292.9	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.3			1.1			1.3	1.1
Adjusted weighted average common shares outstanding – diluted	294.2			294			294.2	294
Net Income for common stock per common share - basic (dollars per share)	$ 1.46			$ 1.49			$ 3.47	$ 3.45
Net Income for common stock per common share - diluted (dollars per share)	$ 1.45			$ 1.48			$ 3.46	$ 3.44

Summary of Significant Accoun38

Summary of Significant Accounting Policies - Changes in Accumulated Other Comprehensive Income/(Loss) by Component (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance, accumulated OCI, net of taxes	$ (39)	$ (20)	$ (45)	$ (25)
OCI before reclassifications, net of tax of $(2) and $(1) for Con Edison in 2015 and 2014, respectively			3	2
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	1	1	4	4
Current period OCI, net of taxes	1	1	7	6
Ending balance, accumulated OCI, net of taxes	(38)	(19)	(38)	(19)
OCI before reclassifications, tax			(2)	(1)
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(1)	(1)	(3)	(3)
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance, accumulated OCI, net of taxes	(10)	(5)	(11)	(6)
OCI before reclassifications, net of tax of $(2) and $(1) for Con Edison in 2015 and 2014, respectively			0	0
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	1	0	2	1
Current period OCI, net of taxes	1	0	2	1
Ending balance, accumulated OCI, net of taxes	$ (9)	$ (5)	$ (9)	$ (5)

Regulatory Matters - Summary of

Regulatory Matters - Summary of Rate Plan (Detail) - Scenario, Forecast - USD ($)	12 Months Ended	26 Months Ended	36 Months Ended
	Dec. 31, 2016	Dec. 31, 2017	Oct. 31, 2018
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Potential refund from customers	$ 249,000,000
Recovery deferral percentage	80.00%
Maximum deferral percentage	30.00%
O&R | Electric
Public Utilities, General Disclosures [Line Items]
Potential penalties (up to)		$ 4,000,000
Deferred storm and property reserve deficiency		59,300,000
Deferred storm and property deficiency not recovered		1,000,000
Storm Reserve | CECONY
Public Utilities, General Disclosures [Line Items]
Revenue requirement	$ 21,000,000
Deferred storm costs | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Amortization of regulatory asset	107,000,000
Reduction of costs recoverable from customers	4,000,000
Property Tax and Interest Rate Reconciliations | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable		4,000,000
Property Tax and Interest Rate Reconciliations | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable			$ 14,000,000
Year 1 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Amortizations to income of net regulatory (assets) liabilities	123,000,000
Retention of annual transmission congestion revenues	90,000,000
Average rate base	$ 18,282,000,000
Weighted average cost of capital (after-tax) (percent)	6.91%
Authorized return on common equity (percent)	9.00%
Earnings sharing percentage	9.60%
Cost of long-term debt (percent)	5.09%
Common equity ratio (percent)	48.00%
Year 1 | CECONY | Electric | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (up to)	$ 400,000,000
Year 1 | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Base rate changes		9,300,000
Amortizations to income of net regulatory (assets) liabilities		(8,500,000)
Net utility plant reconciliations		928,000,000
Average rate base		$ 763,000,000
Weighted average cost of capital (after-tax) (percent)		7.10%
Authorized return on common equity (percent)		9.00%
Earnings sharing percentage		9.60%
Cost of long-term debt (percent)		5.42%
Common equity ratio (percent)		48.00%
Deferred storm and property reserve deficiency		$ 11,850,000
Rate exclusion amount with balance below regulatory threshold		1,000,000
Year 1 | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Base rate changes			16,400,000
Amortizations to income of net regulatory (assets) liabilities			(1,700,000)
Potential penalties (up to)			3,700,000
Net utility plant reconciliations			492,000,000
Average rate base			$ 366,000,000
Weighted average cost of capital (after-tax) (percent)			7.10%
Authorized return on common equity (percent)			9.00%
Earnings sharing percentage			9.60%
Cost of long-term debt (percent)			5.42%
Common equity ratio (percent)			48.00%
Rate exclusion amount with balance below regulatory threshold			$ 500,000
Year 1 | T&D | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations	17,929,000,000
Year 1 | Storm Hardening | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations	268,000,000
Year 1 | Other | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations	$ 2,069,000,000
Year 2 | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Base rate changes		8,800,000
Amortizations to income of net regulatory (assets) liabilities		(9,400,000)
Net utility plant reconciliations		970,000,000
Average rate base		$ 805,000,000
Weighted average cost of capital (after-tax) (percent)		7.06%
Authorized return on common equity (percent)		9.00%
Earnings sharing percentage		9.60%
Cost of long-term debt (percent)		5.35%
Common equity ratio (percent)		48.00%
Deferred storm and property reserve deficiency		$ 11,850,000
Deferred storm and property reserve deficiency period (in years)		5 years
Rate exclusion amount with balance below regulatory threshold		$ 9,000,000
Year 2 | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Base rate changes			16,400,000
Amortizations to income of net regulatory (assets) liabilities			(2,100,000)
Potential penalties (up to)			4,700,000
Net utility plant reconciliations			518,000,000
Average rate base			$ 391,000,000
Weighted average cost of capital (after-tax) (percent)			7.06%
Authorized return on common equity (percent)			9.00%
Earnings sharing percentage			9.60%
Cost of long-term debt (percent)			5.35%
Common equity ratio (percent)			48.00%
Rate exclusion amount with balance below regulatory threshold			$ 4,200,000
Year 3 | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Base rate changes			5,800,000
Base rate changes collected through a surcharge			10,600,000
Amortizations to income of net regulatory (assets) liabilities			(2,500,000)
Potential penalties (up to)			5,800,000
Net utility plant reconciliations			546,000,000
Average rate base			$ 417,000,000
Weighted average cost of capital (after-tax) (percent)			7.06%
Authorized return on common equity (percent)			9.00%
Earnings sharing percentage			9.60%
Cost of long-term debt (percent)			5.35%
Common equity ratio (percent)			48.00%
Rate exclusion amount with balance below regulatory threshold			$ 7,200,000

Regulatory Matters - Additional

Regulatory Matters - Additional Information (Detail) Customer in Millions	1 Months Ended		9 Months Ended
	Oct. 31, 2012Customer	Feb. 28, 2009USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2014USD ($)
Public Utilities, General Disclosures [Line Items]
Annual electric revenue subject to potential refund		$ 249,000,000
Annual gas revenue subject to potential refund		32,000,000
Annual steam revenue subject to potential refund		$ 6,000,000
Potential estimated refund to customers			$ 1,889,000,000
Construction expenditures overcharge consultant estimate			208,000,000
Expected credit to customers			116,000,000
Return on capital expenditures, not recoverable (up to)			55,000,000
Regulatory liabilities			1,940,000,000	$ 1,993,000,000
Prudence proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities			100,000,000	105,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities			1,755,000,000	1,837,000,000
Response and restoration costs			509,000,000
Capital expenditures			148,000,000
CECONY | Prudence proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities			100,000,000	$ 105,000,000
O&R
Public Utilities, General Disclosures [Line Items]
Response and restoration costs			91,000,000
Capital expenditures			$ 15,000,000
Storm Damage
Public Utilities, General Disclosures [Line Items]
Number of customers interrupted electric distribution service | Customer	1.4

Regulatory Matters - Regulatory

Regulatory Matters - Regulatory Assets and Liabilities (Detail) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Regulatory assets
Regulatory assets – noncurrent	$ 8,445	$ 9,156
Regulatory assets – current	67	148
Total Regulatory Assets	8,512	9,304
Regulatory liabilities
Regulatory liabilities – noncurrent	1,940	1,993
Regulatory liabilities – current	165	187
Total Regulatory Liabilities	2,105	2,180
Allowance for cost of removal less salvage
Regulatory liabilities
Regulatory liabilities – noncurrent	633	598
Property tax reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	299	295
Base rate change deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	134	155
Net unbilled revenue deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	134	138
Prudence proceeding
Regulatory liabilities
Regulatory liabilities – noncurrent	100	105
Pension and other postretirement benefit deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	76	46
Variable-rate tax-exempt debt – cost rate reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	75	78
New York State income tax rate change
Regulatory liabilities
Regulatory liabilities – noncurrent	67	62
Property tax refunds
Regulatory liabilities
Regulatory liabilities – noncurrent	55	87
Carrying charges on repair allowance and bonus depreciation
Regulatory liabilities
Regulatory liabilities – noncurrent	50	58
Earnings sharing – electric and steam
Regulatory liabilities
Regulatory liabilities – noncurrent	37	19
Net utility plant reconciliations
Regulatory liabilities
Regulatory liabilities – noncurrent	31	21
World Trade Center settlement proceeds
Regulatory liabilities
Regulatory liabilities – noncurrent	26	41
Unrecognized other postretirement costs
Regulatory liabilities
Regulatory liabilities – noncurrent	20	0
Other
Regulatory liabilities
Regulatory liabilities – noncurrent	203	290
Refundable energy costs
Regulatory liabilities
Regulatory liabilities – current	99	128
Revenue decoupling mechanism
Regulatory liabilities
Regulatory liabilities – current	41	30
Future income tax
Regulatory liabilities
Regulatory liabilities – current	20	24
Deferred derivative gains
Regulatory liabilities
Regulatory liabilities – current	5	5
Unrecognized pension and other postretirement costs
Regulatory assets
Regulatory assets – noncurrent	4,208	4,846
Future income tax
Regulatory assets
Regulatory assets – noncurrent	2,363	2,273
Revenue taxes
Regulatory assets
Regulatory assets – noncurrent	235	219
Deferred storm costs
Regulatory assets
Regulatory assets – noncurrent	218	319
Surcharge for New York State assessment
Regulatory assets
Regulatory assets – noncurrent	68	99
Unamortized loss on reacquired debt
Regulatory assets
Regulatory assets – noncurrent	52	57
Pension and other postretirement benefits deferrals
Regulatory assets
Regulatory assets – noncurrent	49	66
Net electric deferrals
Regulatory assets
Regulatory assets – noncurrent	49	63
O&R property tax reconciliation
Regulatory assets
Regulatory assets – noncurrent	45	36
Deferred derivative losses
Regulatory assets
Regulatory assets – noncurrent	32	25
Preferred stock redemption
Regulatory assets
Regulatory assets – noncurrent	26	27
O&R transition bond charges
Regulatory assets
Regulatory assets – noncurrent	22	27
Recoverable energy costs
Regulatory assets
Regulatory assets – noncurrent	4	19
Regulatory assets – current	1	41
Other
Regulatory assets
Regulatory assets – noncurrent	179	147
Deferred derivative losses
Regulatory assets
Regulatory assets – current	57	97
Future income tax
Regulatory assets
Regulatory assets – current	9	10
CECONY
Regulatory assets
Regulatory assets – noncurrent	7,820	8,481
Regulatory assets – current	53	132
Total Regulatory Assets	7,873	8,613
Regulatory liabilities
Regulatory liabilities – noncurrent	1,755	1,837
Regulatory liabilities – current	135	142
Total Regulatory Liabilities	1,890	1,979
CECONY | Allowance for cost of removal less salvage
Regulatory liabilities
Regulatory liabilities – noncurrent	530	499
CECONY | Property tax reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	299	295
CECONY | Base rate change deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	134	155
CECONY | Net unbilled revenue deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	134	138
CECONY | Prudence proceeding
Regulatory liabilities
Regulatory liabilities – noncurrent	100	105
CECONY | Pension and other postretirement benefit deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	46	37
CECONY | Variable-rate tax-exempt debt – cost rate reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	64	78
CECONY | New York State income tax rate change
Regulatory liabilities
Regulatory liabilities – noncurrent	63	59
CECONY | Property tax refunds
Regulatory liabilities
Regulatory liabilities – noncurrent	55	87
CECONY | Carrying charges on repair allowance and bonus depreciation
Regulatory liabilities
Regulatory liabilities – noncurrent	49	57
CECONY | Earnings sharing – electric and steam
Regulatory liabilities
Regulatory liabilities – noncurrent	37	18
CECONY | Net utility plant reconciliations
Regulatory liabilities
Regulatory liabilities – noncurrent	31	20
CECONY | World Trade Center settlement proceeds
Regulatory liabilities
Regulatory liabilities – noncurrent	26	41
CECONY | Unrecognized other postretirement costs
Regulatory liabilities
Regulatory liabilities – noncurrent	20	0
CECONY | Other
Regulatory liabilities
Regulatory liabilities – noncurrent	167	248
CECONY | Refundable energy costs
Regulatory liabilities
Regulatory liabilities – current	71	84
CECONY | Revenue decoupling mechanism
Regulatory liabilities
Regulatory liabilities – current	39	30
CECONY | Future income tax
Regulatory liabilities
Regulatory liabilities – current	20	24
CECONY | Deferred derivative gains
Regulatory liabilities
Regulatory liabilities – current	5	4
CECONY | Unrecognized pension and other postretirement costs
Regulatory assets
Regulatory assets – noncurrent	4,008	4,609
CECONY | Future income tax
Regulatory assets
Regulatory assets – noncurrent	2,254	2,166
CECONY | Revenue taxes
Regulatory assets
Regulatory assets – noncurrent	223	208
CECONY | Deferred storm costs
Regulatory assets
Regulatory assets – noncurrent	137	224
CECONY | Surcharge for New York State assessment
Regulatory assets
Regulatory assets – noncurrent	63	92
CECONY | Unamortized loss on reacquired debt
Regulatory assets
Regulatory assets – noncurrent	50	55
CECONY | Pension and other postretirement benefits deferrals
Regulatory assets
Regulatory assets – noncurrent	21	42
CECONY | Net electric deferrals
Regulatory assets
Regulatory assets – noncurrent	49	63
CECONY | O&R property tax reconciliation
Regulatory assets
Regulatory assets – noncurrent	0	0
CECONY | Deferred derivative losses
Regulatory assets
Regulatory assets – noncurrent	28	23
CECONY | Preferred stock redemption
Regulatory assets
Regulatory assets – noncurrent	26	27
CECONY | O&R transition bond charges
Regulatory assets
Regulatory assets – noncurrent	0	0
CECONY | Recoverable energy costs
Regulatory assets
Regulatory assets – noncurrent	4	17
Regulatory assets – current	1	40
CECONY | Other
Regulatory assets
Regulatory assets – noncurrent	162	127
CECONY | Deferred derivative losses
Regulatory assets
Regulatory assets – current	52	92
CECONY | Future income tax
Regulatory assets
Regulatory assets – current	0	0
Superfund Sites
Regulatory assets
Total Regulatory Assets	884	925
Superfund Sites | Environmental remediation costs
Regulatory assets
Regulatory assets – noncurrent	884	925
Superfund Sites | CECONY
Regulatory assets
Total Regulatory Assets	784	820
Superfund Sites | CECONY | Environmental remediation costs
Regulatory assets
Regulatory assets – noncurrent	784	820
Workers’ compensation
Regulatory assets
Total Regulatory Assets	11	8
Workers’ compensation | Workers’ compensation
Regulatory assets
Regulatory assets – noncurrent	11	8
Workers’ compensation | CECONY
Regulatory assets
Total Regulatory Assets	11	8
Workers’ compensation | CECONY | Workers’ compensation
Regulatory assets
Regulatory assets – noncurrent	$ 11	$ 8

Capitalization - Carrying Amoun

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Detail) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Carrying Amount	$ 12,282	$ 12,191
Fair Value	13,575	13,998
CECONY
Debt Instrument [Line Items]
Carrying Amount	11,215	11,214
Fair Value	$ 12,385	$ 12,846

Capitalization - Additional Inf

Capitalization - Additional Information (Detail)	1 Months Ended		9 Months Ended
	Aug. 31, 2015USD ($)	Apr. 30, 2015USD ($)	Sep. 30, 2015USD ($)project	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Schedule of Capitalization [Line Items]
Proceeds from long-term debt			$ 238,000,000	$ 850,000,000
Number of solar projects securing notes | project			4
Long-term debt, fair value			$ 13,575,000,000		$ 13,998,000,000
Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value			12,939,000,000
Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value			636,000,000
CECONY
Schedule of Capitalization [Line Items]
Proceeds from long-term debt			0	$ 850,000,000
Long-term debt, fair value			12,385,000,000		$ 12,846,000,000
CECONY | Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value			11,749,000,000
CECONY | Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value			636,000,000
Tax-exempt debt			636,000,000
Secured Debt | 5.30% debentures | O&R
Schedule of Capitalization [Line Items]
Proceeds from long-term debt		$ 40,000,000
Debt instrument, interest rate (percent)		5.30%
Debt Instrument, term (in years)		10 years
Secured Debt | 4.95% debentures due 2045 | O&R
Schedule of Capitalization [Line Items]
Debt Instrument, face amount			$ 120,000,000
Debt instrument, interest rate (percent)			4.95%
Secured Debt | 2.50% debentures | O&R
Schedule of Capitalization [Line Items]
Proceeds from long-term debt	$ 55,000,000
Debt instrument, interest rate (percent)	2.50%
Debt Instrument, term (in years)	5 years
Secured Debt | Variable Rate Tax-Exempt 20 Year Debt | O&R
Schedule of Capitalization [Line Items]
Proceeds from long-term debt	$ 44,000,000
Debt Instrument, term (in years)	20 years
Senior Notes | 3.94% Senior Notes due 2036 | Con Edison Development
Schedule of Capitalization [Line Items]
Debt Instrument, face amount			$ 118,000,000
Debt instrument, interest rate (percent)			3.94%

Short-Term Borrowing - Addition

Short-Term Borrowing - Additional Information (Detail) - USD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 1,160,000,000	$ 800,000,000
Weighted average interest rate (percent)	0.30%	0.40%
Loans outstanding under credit agreement	$ 0	$ 0
Letters of credit outstanding under the Credit Agreement	56,000,000	11,000,000
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 649,000,000	$ 450,000,000
Weighted average interest rate (percent)	0.30%	0.40%
Letters of credit outstanding under the Credit Agreement	$ 11,000,000	$ 11,000,000

Pension Benefits - Total Period

Pension Benefits - Total Periodic Benefit Costs (Detail) - Pension Benefits - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 74	$ 57	$ 223	$ 170
Interest cost on projected benefit obligation	144	143	431	429
Expected return on plan assets	(222)	(208)	(664)	(624)
Recognition of net actuarial loss	194	154	581	464
Recognition of prior service costs	1	1	3	3
NET PERIODIC BENEFIT COST	191	147	574	442
Amortization of regulatory asset	1	1	2	2
TOTAL PERIODIC BENEFIT COST	192	148	576	444
Cost capitalized	(80)	(57)	(224)	(166)
Reconciliation to rate level	(14)	30	(56)	86
Cost charged to operating expenses	98	121	296	364
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	70	53	209	158
Interest cost on projected benefit obligation	135	134	404	402
Expected return on plan assets	(210)	(198)	(630)	(592)
Recognition of net actuarial loss	183	146	550	439
Recognition of prior service costs	0	1	1	2
NET PERIODIC BENEFIT COST	178	136	534	409
Amortization of regulatory asset	1	1	2	2
TOTAL PERIODIC BENEFIT COST	179	137	536	411
Cost capitalized	(76)	(54)	(214)	(156)
Reconciliation to rate level	(14)	28	(56)	78
Cost charged to operating expenses	$ 89	$ 111	$ 266	$ 333

Pension Benefits - Additional I

Pension Benefits - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 750
Contributions	747
CECONY | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	697
Contributions	694
CECONY | Non-qualified Supplemental Plan
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 16

Other Postretirement Benefits -

Other Postretirement Benefits - Total Periodic Postretirement Benefit Costs (Detail) - Other Postretirement Benefits - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 5	$ 5	$ 15	$ 14
Interest cost on accumulated other postretirement benefit obligation	13	15	38	45
Expected return on plan assets	(20)	(19)	(59)	(58)
Recognition of net actuarial loss	8	14	24	43
Recognition of prior service cost	(5)	(5)	(15)	(14)
NET PERIODIC BENEFIT COST	1	10	3	30
Cost capitalized	(1)	(4)	(2)	(11)
Reconciliation to rate level	4	3	12	8
Cost charged to operating expenses	4	9	13	27
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	4	11	11
Interest cost on accumulated other postretirement benefit obligation	11	13	32	39
Expected return on plan assets	(17)	(17)	(51)	(51)
Recognition of net actuarial loss	7	13	21	38
Recognition of prior service cost	(4)	(4)	(10)	(11)
NET PERIODIC BENEFIT COST	1	9	3	26
Cost capitalized	(1)	(4)	(2)	(10)
Reconciliation to rate level	2	1	5	2
Cost charged to operating expenses	$ 2	$ 6	$ 6	$ 18

Other Postretirement Benefits48

Other Postretirement Benefits - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 6

Environmental Matters - Accrued

Environmental Matters - Accrued Liabilities and Regulatory Assets (Detail) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Accrued Liabilities:
Accrued Liabilities	$ 746	$ 764
Regulatory assets	8,512	9,304
Manufactured gas plant sites
Accrued Liabilities:
Accrued Liabilities	666	684
Other Superfund Sites
Accrued Liabilities:
Accrued Liabilities	80	80
Superfund Sites
Accrued Liabilities:
Accrued Liabilities	746	764
Regulatory assets	884	925
CECONY
Accrued Liabilities:
Accrued Liabilities	651	666
Regulatory assets	7,873	8,613
CECONY | Manufactured gas plant sites
Accrued Liabilities:
Accrued Liabilities	572	587
CECONY | Other Superfund Sites
Accrued Liabilities:
Accrued Liabilities	79	79
CECONY | Superfund Sites
Accrued Liabilities:
Accrued Liabilities	651	666
Regulatory assets	$ 784	$ 820

Environmental Matters - Environ

Environmental Matters - Environmental Remediation Costs (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 6	$ 5	$ 21	$ 19
Insurance recoveries received	0	0	0	5
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	6	2	18	12
Insurance recoveries received	$ 0	$ 0	$ 0	$ 5

Environmental Matters - Additio

Environmental Matters - Additional Information (Detail) - USD ($)	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability	$ 8,000,000	$ 8,000,000
Estimated undiscounted asbestos liability in year	15 years
Manufactured gas plant sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)		2,700,000,000
CECONY | Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability	$ 7,000,000	7,000,000
Estimated undiscounted asbestos liability in year	15 years
CECONY | Manufactured gas plant sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)		$ 2,500,000,000

Environmental Matters - Accru52

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Detail) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Site Contingency [Line Items]
Regulatory assets	$ 8,512	$ 9,304
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers’ compensation
Site Contingency [Line Items]
Accrued liability	86	83
Regulatory assets	11	8
CECONY
Site Contingency [Line Items]
Regulatory assets	7,873	8,613
CECONY | Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY | Workers’ compensation
Site Contingency [Line Items]
Accrued liability	81	78
Regulatory assets	$ 11	$ 8

Other Material Contingencies -

Other Material Contingencies - Additional Information (Detail)	Mar. 12, 2014buildingPersonlawsuit	Jul. 31, 2007Personlawsuit	Sep. 30, 2015USD ($)	Dec. 31, 2014USD ($)
Guarantor Obligations [Line Items]
Number of person died in steam ruptured | Person		1
Number of suits pending against the company | lawsuit		90
Estimated accrued liability for suits			$ 50,000,000
Number of buildings destroyed by fire | building	2
Insurance receivable for suits			50,000,000
Number of people died in explosion and fire incident | Person	8
Number of people injured in explosion and fire incident | Person	50
Guarantee obligations maximum exposure			$ 2,576,000,000	$ 2,547,000,000
Ownership interest, percentage				46.00%
Estimated project cost percentage			175.00%
Manhattan Explosion and Fire
Guarantor Obligations [Line Items]
Number of suits pending against the company | lawsuit	70
Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 30,000,000
Indemnity agreements amount			25,000,000
Electric provider obligation to Public Utility Commission of Texas			5,000,000
Construction and Operation of Solar Energy Facilities
Guarantor Obligations [Line Items]
Guarantees issued			$ 3,000,000

Other Material Contingencies 54

Other Material Contingencies - Total Guarantees (Detail) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,576	$ 2,547
NY Transco
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	1,359
Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	885
Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	302
Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	30
0-3 years
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	1,912
0-3 years | NY Transco
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	946
0-3 years | Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	760
0-3 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	176
0-3 years | Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	30
4-10 years
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	531
4-10 years | NY Transco
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	413
4-10 years | Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	36
4-10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	82
4-10 years | Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	0
Greater than 10 years
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	133
Greater than 10 years | NY Transco
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	0
Greater than 10 years | Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	89
Greater than 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	44
Greater than 10 years | Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 0

Income Tax - Additional Informa

Income Tax - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income Taxes Disclosure [Line Items]
Income tax expense	$ 249	$ 259	$ 548	$ 559
Effective tax rate	37.00%	37.00%	35.00%	36.00%
Requested refund adjustment from settlement with taxing authority	$ 30		$ 30
Estimated liability for uncertain tax positions	34		34
Uncertain tax positions, reasonably possible to resolve within twelve months	25		25
Uncertain tax positions, reasonably possible to resolve within twelve months, net of federal taxes	16		16
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate	34		34
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate, net of federal taxes	22		22
CECONY
Income Taxes Disclosure [Line Items]
Income tax expense	$ 222	$ 233	$ 515	$ 496
Effective tax rate	37.00%	37.00%	35.00%	35.00%
Estimated liability for uncertain tax positions	$ 2		$ 2
Uncertain tax positions, reasonably possible to resolve within twelve months	2		2
Uncertain tax positions, reasonably possible to resolve within twelve months, net of federal taxes	$ 1		$ 1

Financial Information by Busi56

Financial Information by Business Segment - Financial Data for Business Segments (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Segment Reporting Information [Line Items]
Operating revenues	$ 3,443	$ 3,390	$ 9,847	$ 10,091
Depreciation and amortization	285	270	840	796
Operating income	830	819	2,028	1,959
CECONY
Segment Reporting Information [Line Items]
Operating revenues	2,829	2,838	8,122	8,479
Depreciation and amortization	262	250	773	737
Operating income	745	756	1,889	1,786
CECONY | Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	207	198	610	581
Operating income	811	811	1,511	1,416
CECONY | Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	35	33	105	98
Operating income	(17)	(14)	278	273
CECONY | Steam
Segment Reporting Information [Line Items]
Depreciation and amortization	20	19	58	58
Operating income	(49)	(41)	100	97
O&R
Segment Reporting Information [Line Items]
Depreciation and amortization	17	16	51	45
Operating income	42	43	85	102
O&R | Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	13	12	38	33
Operating income	51	51	85	87
O&R | Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	4	4	13	12
Operating income	(9)	(8)	0	15
Competitive energy businesses
Segment Reporting Information [Line Items]
Depreciation and amortization	6	3	16	14
Operating income	43	20	53	70
Other
Segment Reporting Information [Line Items]
Depreciation and amortization	0	1	0	0
Operating income	0	0	1	1
Operating revenues
Segment Reporting Information [Line Items]
Operating revenues	3,443	3,390	9,847	10,091
Operating revenues | CECONY
Segment Reporting Information [Line Items]
Operating revenues	2,829	2,838	8,122	8,479
Operating revenues | CECONY | Electric
Segment Reporting Information [Line Items]
Operating revenues	2,558	2,582	6,416	6,635
Operating revenues | CECONY | Gas
Segment Reporting Information [Line Items]
Operating revenues	213	210	1,177	1,359
Operating revenues | CECONY | Steam
Segment Reporting Information [Line Items]
Operating revenues	58	46	529	485
Operating revenues | O&R
Segment Reporting Information [Line Items]
Operating revenues	229	232	640	680
Operating revenues | O&R | Electric
Segment Reporting Information [Line Items]
Operating revenues	205	205	523	525
Operating revenues | O&R | Gas
Segment Reporting Information [Line Items]
Operating revenues	24	27	117	155
Operating revenues | Competitive energy businesses
Segment Reporting Information [Line Items]
Operating revenues	386	321	1,087	934
Operating revenues | Other
Segment Reporting Information [Line Items]
Operating revenues	(1)	(1)	(2)	(2)
Inter-segment revenues | CECONY
Segment Reporting Information [Line Items]
Operating revenues	(27)	(26)	(82)	(78)
Inter-segment revenues | CECONY | Electric
Segment Reporting Information [Line Items]
Operating revenues	4	4	13	12
Inter-segment revenues | CECONY | Gas
Segment Reporting Information [Line Items]
Operating revenues	1	1	4	4
Inter-segment revenues | CECONY | Steam
Segment Reporting Information [Line Items]
Operating revenues	22	21	65	62
Inter-segment revenues | Competitive energy businesses
Segment Reporting Information [Line Items]
Operating revenues	(2)	(3)	(5)	(2)
Inter-segment revenues | Other
Segment Reporting Information [Line Items]
Operating revenues	$ 2	$ 3	$ 5	$ 2

Derivative Instruments and He57

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Detail) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Net Amounts of Assets/ (Liabilities)	$ 326	$ 361
Net Amounts of Assets/ (Liabilities)	(112)	(78)
Gross Amounts of Recognized Assets/(Liabilities)	(135)	(163)
Gross Amounts Offset	39	140
Net Amounts of Assets/ (Liabilities)	(96)	(23)
Margin deposits	17	27
Fair Value of Derivative Assets, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	47	111
Gross Amounts Offset	(33)	(67)
Net Amounts of Assets/ (Liabilities)	14	44
Fair Value of Derivative Assets, Assets Held for Sale, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	39	0
Gross Amounts Offset	(39)	0
Net Amounts of Assets/ (Liabilities)	0	0
Fair Value of Derivative Assets, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	19	34
Gross Amounts Offset	(17)	(23)
Net Amounts of Assets/ (Liabilities)	2	11
Fair Value of Derivative Assets
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	105	145
Gross Amounts Offset	(89)	(90)
Net Amounts of Assets/ (Liabilities)	16	55
Fair Value of Derivative Liabilities, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(84)	(242)
Gross Amounts Offset	58	139
Net Amounts of Assets/ (Liabilities)	(26)	(103)
Fair Value of Derivative Liabilities, Liabilities Held For Sale, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(77)	0
Gross Amounts Offset	30	0
Net Amounts of Assets/ (Liabilities)	(47)	0
Fair Value of Derivative Liabilities, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(48)	(66)
Gross Amounts Offset	31	91
Net Amounts of Assets/ (Liabilities)	(17)	25
Fair Value of Derivative Liabilities, Liabilities Held For Sale, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(31)	0
Gross Amounts Offset	9	0
Net Amounts of Assets/ (Liabilities)	(22)	0
Fair Value of Derivative Liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(240)	(308)
Gross Amounts Offset	128	230
Net Amounts of Assets/ (Liabilities)	(112)	(78)
CECONY
Derivatives, Fair Value [Line Items]
Net Amounts of Assets/ (Liabilities)	297	299
Gross Amounts of Recognized Assets/(Liabilities)	(62)	(90)
Gross Amounts Offset	38	45
Net Amounts of Assets/ (Liabilities)	(24)	(45)
Margin deposits	17	25
CECONY | Fair Value of Derivative Assets, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	36	26
Gross Amounts Offset	(28)	(15)
Net Amounts of Assets/ (Liabilities)	8	11
CECONY | Fair Value of Derivative Assets, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	16	22
Gross Amounts Offset	(15)	(20)
Net Amounts of Assets/ (Liabilities)	1	2
CECONY | Fair Value of Derivative Assets
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	52	48
Gross Amounts Offset	(43)	(35)
Net Amounts of Assets/ (Liabilities)	9	13
CECONY | Fair Value of Derivative Liabilities, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(72)	(96)
Gross Amounts Offset	53	48
Net Amounts of Assets/ (Liabilities)	(19)	(48)
CECONY | Fair Value of Derivative Liabilities, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(42)	(42)
Gross Amounts Offset	28	32
Net Amounts of Assets/ (Liabilities)	(14)	(10)
CECONY | Fair Value of Derivative Liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(114)	(138)
Gross Amounts Offset	81	80
Net Amounts of Assets/ (Liabilities)	$ (33)	$ (58)

Derivative Instruments and He58

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (1)	$ (11)	$ 0	$ 26
Total deferred gains/(losses)	(31)	(36)	(59)	67
Net deferred gains/(losses)	(32)	(47)	(59)	93
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(52)	(37)	(134)	69
Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(1)	(6)	0	25
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	(5)	0	1
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	8	(6)	40	10
Recoverable energy costs
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(53)	(33)	(92)	54
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	14	3	(7)	3
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(1)	(10)	1	21
Total deferred gains/(losses)	(28)	(31)	(52)	53
Net deferred gains/(losses)	(29)	(41)	(51)	74
CECONY | Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(1)	(5)	1	20
CECONY | Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	(5)	0	1
CECONY | Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	8	(5)	40	10
CECONY | Recoverable energy costs
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(49)	(29)	(87)	41
CECONY | Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	13	3	(5)	2
Non Utility Operating Revenue
Pre-tax gain/(loss) recognized in income
Unrealized gain (loss) on derivatives			(3)
Purchased power expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(31)	(28)	(60)	134
Unrealized gain (loss) on derivatives	12	(1)	6	14
Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(26)	(29)	(94)	(75)
Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 5	$ 20	$ 20	$ 10

Derivative Instruments and He59

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Detail)	9 Months Ended
	Sep. 30, 2015DTHMWhMWgal
Electric Energy Derivative
Derivatives, Fair Value [Line Items]
Electric Energy (MWHs) | MWh	18,475,688
Electric Capacity Derivative
Derivatives, Fair Value [Line Items]
Capacity (MWs)	7,201
Natural Gas Derivative
Derivatives, Fair Value [Line Items]
Natural Gas (Dt) | DTH	63,386,967
Refined Fuels
Derivatives, Fair Value [Line Items]
Refined fuel (gallons) | gal	4,620,000
CECONY | Electric Energy Derivative
Derivatives, Fair Value [Line Items]
Electric Energy (MWHs) | MWh	5,972,325
CECONY | Electric Capacity Derivative
Derivatives, Fair Value [Line Items]
Capacity (MWs)	2,400
CECONY | Natural Gas Derivative
Derivatives, Fair Value [Line Items]
Natural Gas (Dt) | DTH	56,690,000
CECONY | Refined Fuels
Derivatives, Fair Value [Line Items]
Refined fuel (gallons) | gal	4,620,000
Discontinued Operations, Held-for-sale | Electric Energy Derivative
Derivatives, Fair Value [Line Items]
Electric Energy (MWHs) | MWh	11,445,799
Discontinued Operations, Held-for-sale | Electric Capacity Derivative
Derivatives, Fair Value [Line Items]
Capacity (MWs)	5,436
Discontinued Operations, Held-for-sale | Natural Gas Derivative
Derivatives, Fair Value [Line Items]
Natural Gas (Dt) | DTH	509,294

Derivative Instruments and He60

Derivative Instruments and Hedging Activities - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 154
Makeup of net credit exposure with commodity exchange brokers	71
Makeup of net credit exposure independent system operators	69
Makeup of net credit exposure with investment-grade counterparties	7
Makeup of net credit exposure non-investment grade/non-rated counterparties	7
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 17

Derivative Instruments and He61

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Detail) $ in Millions	Sep. 30, 2015USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 52
Collateral posted	5
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	1
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	72
Derivatives in net asset position additional collateral	9
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	3
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	32
Collateral posted	0
CECONY | Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	0
CECONY | Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	$ 43

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - USD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 326,000,000	$ 361,000,000
Derivative liabilities	112,000,000	78,000,000
Transfers between levels 1,2 and 3	0	0
CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	297,000,000	299,000,000
Transfers between levels 1,2 and 3	0	0
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	182,000,000	166,000,000
Derivative liabilities	14,000,000	18,000,000
Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	168,000,000	156,000,000
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	164,000,000	194,000,000
Derivative liabilities	179,000,000	246,000,000
Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	111,000,000	109,000,000
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	11,000,000	28,000,000
Derivative liabilities	7,000,000	8,000,000
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	33,000,000	82,000,000
Derivative liabilities	43,000,000	78,000,000
Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	26,000,000	38,000,000
Derivative liabilities	33,000,000	58,000,000
Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1,000,000	3,000,000
Derivative liabilities	12,000,000	18,000,000
Commodity | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1,000,000	1,000,000
Derivative liabilities	11,000,000	16,000,000
Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	15,000,000	78,000,000
Derivative liabilities	80,000,000	246,000,000
Commodity | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	7,000,000	3,000,000
Derivative liabilities	67,000,000	91,000,000
Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	11,000,000	28,000,000
Derivative liabilities	1,000,000	8,000,000
Commodity | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	8,000,000	13,000,000
Derivative liabilities	0	0
Commodity Contract, Held For Sale
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	69,000,000	0
Commodity Contract, Held For Sale | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	2,000,000	0
Commodity Contract, Held For Sale | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	37,000,000	0
Derivative liabilities	99,000,000	0
Commodity Contract, Held For Sale | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	6,000,000	0
Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	293,000,000	279,000,000
Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	271,000,000	261,000,000
Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	181,000,000	163,000,000
Other | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	167,000,000	155,000,000
Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	112,000,000	116,000,000
Other | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	104,000,000	106,000,000
Other | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Other | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Netting Adjustments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(31,000,000)	(27,000,000)
Derivative liabilities	(88,000,000)	(194,000,000)
Netting Adjustments | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6,000,000	(27,000,000)
Derivative liabilities	(50,000,000)	(194,000,000)
Netting Adjustments | Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	10,000,000	21,000,000
Derivative liabilities	(45,000,000)	(49,000,000)
Netting Adjustments | Commodity Contract, Held For Sale
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(37,000,000)	0
Derivative liabilities	(38,000,000)	0
Netting Adjustments | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Netting Adjustments | Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 0	$ 0

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Commodity Derivatives (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2015USD ($)$ / kW-month$ / MWh
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Transmission Congestion Contracts/Financial Transmission Rights
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Minimum | Discount to Adjust Auction Prices for Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	40.80%
Minimum | Discount to Adjust Auction Prices for Historical Monthly Realized Settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	37.50%
Minimum | Inter-Zonal Forward Price Curves Adjusted for Historical Zonal Losses
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per kW-month)	(5.30)
Minimum | Forward Energy Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH/Dt)	18.5
Minimum | Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH/Dt) | $ / kW-month	2.96
Maximum | Discount to Adjust Auction Prices for Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	57.90%
Maximum | Discount to Adjust Auction Prices for Historical Monthly Realized Settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	82.20%
Maximum | Inter-Zonal Forward Price Curves Adjusted for Historical Zonal Losses
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per kW-month)	2.94
Maximum | Forward Energy Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH/Dt)	91.75
Maximum | Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH/Dt) | $ / kW-month	15.01
Level 3
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives | $	$ 4
Level 3 | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives | $	(5)
Level 3 | Transmission Congestion Contracts/Financial Transmission Rights
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives | $	$ 9
CECONY | Transmission Congestion Contracts
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
CECONY | Minimum | Discount to Adjust Auction Prices for Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	40.80%
CECONY | Minimum | Discount to Adjust Auction Prices for Historical Monthly Realized Settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	37.50%
CECONY | Maximum | Discount to Adjust Auction Prices for Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	57.90%
CECONY | Maximum | Discount to Adjust Auction Prices for Historical Monthly Realized Settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	82.20%
CECONY | Level 3 | Transmission Congestion Contracts
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives | $	$ 8

Fair Value Measurements - Recon

Fair Value Measurements - Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 13	$ 27	$ 20	$ 9
Included in earnings	(4)	(8)	(18)	41
Included in regulatory assets and liabilities	(1)	(4)	(1)	4
Purchases	1	3	9	15
Settlements	(5)	3	(6)	(48)
Ending balance	4	21	4	21
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	11	14	13	6
Included in earnings	(1)	(3)	(5)	6
Included in regulatory assets and liabilities	(1)	(4)	(1)	4
Purchases	1	3	5	13
Settlements	(2)	1	(4)	(18)
Ending balance	$ 8	$ 11	$ 8	$ 11

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Purchased power expense
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value, assets measured on recurring basis, change in unrealized gain (loss)	$ (3)	$ (2)	$ (8)	$ 8
Competitive energy businesses
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative liabilities	$ (3)	$ (5)	$ (12)	$ 35

Variable Interest Entities - Ad

Variable Interest Entities - Additional Information (Detail)	Sep. 30, 2015USD ($)MW	Sep. 30, 2015USD ($)	Sep. 30, 2015USD ($)MW	Dec. 31, 2014USD ($)entity
Variable Interest Entity [Line Items]
Investments	$ 874,000,000	$ 874,000,000	$ 874,000,000	$ 816,000,000
Cogen Technologies Linden Venture, LP
Variable Interest Entity [Line Items]
Maximum exposure to loss	255,000,000	255,000,000	255,000,000
Brooklyn Navy Yard Cogeneration Partners, LP
Variable Interest Entity [Line Items]
Maximum exposure to loss	83,000,000	83,000,000	83,000,000
Indeck Energy Services of Corinth, Inc
Variable Interest Entity [Line Items]
Maximum exposure to loss	25,000,000	25,000,000	$ 25,000,000
Variable Interest Entity, Not Primary Beneficiary, Aggregated Disclosure
Variable Interest Entity [Line Items]
Percentage of variable interests			50.00%
CECONY
Variable Interest Entity [Line Items]
Number of potential VIEs, long-term electricity purchase agreements | entity				3
Investments	281,000,000	$ 281,000,000	$ 281,000,000	$ 271,000,000
Panoche Valley | Variable Interest Entity, Not Primary Beneficiary, Aggregated Disclosure
Variable Interest Entity [Line Items]
Percentage of variable interests		50.00%
Investments	33,000,000	$ 33,000,000	33,000,000
Notes receivable	25,000,000	25,000,000	25,000,000
California | Panoche Valley | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entity [Line Items]
Maximum exposure to loss	$ 58,000,000	$ 58,000,000	$ 58,000,000
Generating Capacity (MWs AC) | MW	247		124

Variable Interest Entities - Su

Variable Interest Entities - Summary of VIEs (Detail)	Sep. 30, 2015USD ($)MW	Sep. 30, 2015USD ($)	Sep. 30, 2015USD ($)MW
Pilesgrove | Minimum | Solar Renewable Energy Credit Hedge
Variable Interest Entity [Line Items]
Renewable Energy Credit			3 years
Pilesgrove | Maximum | Solar Renewable Energy Credit Hedge
Variable Interest Entity [Line Items]
Renewable Energy Credit			5 years
Variable Interest Entity, Not Primary Beneficiary, Aggregated Disclosure
Variable Interest Entity [Line Items]
Percentage of variable interests			50.00%
Variable Interest Entity, Not Primary Beneficiary, Aggregated Disclosure | Panoche Valley
Variable Interest Entity [Line Items]
Percentage of variable interests		50.00%
Variable Interest Entity, Not Primary Beneficiary | Copper Mountain Solar 3 | Nevada
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW			128
Power Purchase Agreement Term in Years			20 years
Year of Initial Investment			2,014
Maximum exposure to loss	$ 189,000,000	$ 189,000,000	$ 189,000,000
Variable Interest Entity, Not Primary Beneficiary | Mesquite Solar 1 | Arizona
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW			83
Power Purchase Agreement Term in Years			20 years
Year of Initial Investment			2,013
Maximum exposure to loss	108,000,000	108,000,000	$ 108,000,000
Variable Interest Entity, Not Primary Beneficiary | Copper Mountain Solar 2 | Nevada
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW			75
Power Purchase Agreement Term in Years			25 years
Year of Initial Investment			2,013
Maximum exposure to loss	85,000,000	85,000,000	$ 85,000,000
Variable Interest Entity, Not Primary Beneficiary | California Solar | California
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW			55
Power Purchase Agreement Term in Years			25 years
Year of Initial Investment			2,012
Maximum exposure to loss	$ 76,000,000	76,000,000	$ 76,000,000
Variable Interest Entity, Not Primary Beneficiary | Panoche Valley | California
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW	247		124
Power Purchase Agreement Term in Years			20 years
Year of Initial Investment			2,015
Maximum exposure to loss	$ 58,000,000	58,000,000	$ 58,000,000
Variable Interest Entity, Not Primary Beneficiary | Broken Bow II | Nebraska
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW			37
Power Purchase Agreement Term in Years			25 years
Year of Initial Investment			2,014
Maximum exposure to loss	55,000,000	55,000,000	$ 55,000,000
Variable Interest Entity, Not Primary Beneficiary | Pilesgrove | New Jersey
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW			9
Year of Initial Investment			2,010
Maximum exposure to loss	26,000,000	26,000,000	$ 26,000,000
Variable Interest Entity, Primary Beneficiary | Texas Solar 4
Variable Interest Entity [Line Items]
Percentage of variable interests			80.00%
VIEs, noncontrolling interest	9,000,000	9,000,000	$ 9,000,000
Variable Interest Entity, Primary Beneficiary | Texas Solar 4 | Texas
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW			32
Power Purchase Agreement Term in Years			25 years
Year of Initial Investment			2,014
Maximum exposure to loss	$ 49,000,000	$ 49,000,000	$ 49,000,000

Assets Held For Sale (Details)

Assets Held For Sale (Details) - USD ($)	Sep. 30, 2015	Oct. 31, 2015	Jun. 30, 2015	Dec. 31, 2014	Sep. 30, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and temporary cash investments	$ 2,000,000				$ 0
Total current assets	194,000,000			$ 0
Non-utility property, less accumulated depreciation of $13	572,000,000			388,000,000
Total current liabilities	82,000,000			$ 0
Discontinued Operations, Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and temporary cash investments	2,000,000
Accounts receivable	89,000,000
Accrued unbilled revenue	78,000,000
Other assets	3,000,000
Total current assets	172,000,000
Utility plant, less accumulated depreciation of $6	14,000,000
Non-utility property, less accumulated depreciation of $13	4,000,000
Regulatory assets	4,000,000
Total assets held for sale	194,000,000
Derivative liabilities	47,000,000
Accounts payable	6,000,000
Other	3,000,000
Total current liabilities	56,000,000
Derivative liabilities	22,000,000
Long-term debt	3,000,000
Other deferred credits and noncurrent liabilities	1,000,000
Total liabilities held for sale	82,000,000
Depreciation, utility plant	6,000,000
Depreciation, non-utility property	13,000,000
Impairment of long-lived assets to be disposed of			$ 0
Retail Electric Supply Business | Discontinued Operations, Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and temporary cash investments	0
Accounts receivable	89,000,000
Accrued unbilled revenue	78,000,000
Other assets	2,000,000
Total current assets	169,000,000
Utility plant, less accumulated depreciation of $6	0
Non-utility property, less accumulated depreciation of $13	4,000,000
Regulatory assets	0
Total assets held for sale	173,000,000
Derivative liabilities	47,000,000
Accounts payable	6,000,000
Other	2,000,000
Total current liabilities	55,000,000
Derivative liabilities	22,000,000
Long-term debt	0
Other deferred credits and noncurrent liabilities	0
Total liabilities held for sale	77,000,000
Pike | Discontinued Operations, Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and temporary cash investments	2,000,000
Accounts receivable	0
Accrued unbilled revenue	0
Other assets	1,000,000
Total current assets	3,000,000
Utility plant, less accumulated depreciation of $6	14,000,000
Non-utility property, less accumulated depreciation of $13	0
Regulatory assets	4,000,000
Total assets held for sale	21,000,000
Derivative liabilities	0
Accounts payable	0
Other	1,000,000
Total current liabilities	1,000,000
Derivative liabilities	0
Long-term debt	3,000,000
Other deferred credits and noncurrent liabilities	1,000,000
Total liabilities held for sale	5,000,000
Impairment of long-lived assets to be disposed of	5,000,000
Impairment of long-lived assets to be disposed of, net of taxes	$ 3,000,000
Subsequent Event | Pike | Discontinued Operations, Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture of business		$ 16,000,000