Document and Entity Information - shares	6 Months Ended
Document and Entity Information - shares	Jun. 30, 2016	Jul. 29, 2016
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Trading Symbol	ED
Entity Registrant Name	CONSOLIDATED EDISON INC
Entity Central Index Key	0001047862
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		304,414,974
CECONY
Document Information [Line Items]
Entity Registrant Name	CONSOLIDATED EDISON CO OF NEW YORK INC
Entity Central Index Key	0000023632
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

Consolidated Income Statement (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
OPERATING REVENUES
Electric	$ 2,035	$ 2,040	$ 3,947	$ 4,175
Gas	336	324	1,012	1,056
Steam	85	96	343	471
Non-utility	338	328	648	702
TOTAL OPERATING REVENUES	2,794	2,788	5,950	6,404
OPERATING EXPENSES
Purchased power	558	660	1,249	1,544
Fuel	33	31	104	185
Gas purchased for resale	81	89	239	351
Other operations and maintenance	820	802	1,607	1,616
Depreciation and amortization	302	276	599	555
Taxes, other than income taxes	485	458	995	955
TOTAL OPERATING EXPENSES	2,279	2,316	4,793	5,206
OPERATING INCOME	515	472	1,157	1,198
OTHER INCOME (DEDUCTIONS)
Investment and other income	15	14	19	19
Allowance for equity funds used during construction	2	1	4	2
Other deductions	(6)	(5)	(11)	(7)
TOTAL OTHER INCOME (DEDUCTIONS)	11	10	12	14
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	526	482	1,169	1,212
INTEREST EXPENSE
Interest on long-term debt	167	156	330	311
Other interest	5	7	12	13
Allowance for borrowed funds used during construction	(2)	(1)	(3)	(1)
NET INTEREST EXPENSE	170	162	339	323
INCOME BEFORE INCOME TAX EXPENSE	356	320	830	889
INCOME TAX EXPENSE	124	101	288	300
NET INCOME	$ 232	$ 219	$ 542	$ 589
Net income per common share-basic (dollars per share)	$ 0.78	$ 0.75	$ 1.83	$ 2.01
Net income per common share-diluted (dollars per share)	0.77	0.74	1.82	2.01
DIVIDENDS DECLARED PER COMMON SHARE (dollars per share)	$ 0.67	$ 0.65	$ 1.34	$ 1.30
AVERAGE NUMBER OF SHARES OUTSTANDING-BASIC (IN MILLIONS) (shares)	299.1	292.9	296.7	292.9
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS) (shares)	300.4	294.0	298.0	293.9
CECONY
OPERATING REVENUES
Electric	$ 1,892	$ 1,879	$ 3,665	$ 3,858
Gas	304	308	905	963
Steam	85	96	343	471
TOTAL OPERATING REVENUES	2,281	2,283	4,913	5,292
OPERATING EXPENSES
Purchased power	369	358	721	897
Fuel	33	31	104	185
Gas purchased for resale	51	54	183	252
Other operations and maintenance	701	687	1,381	1,390
Depreciation and amortization	275	254	547	511
Taxes, other than income taxes	460	439	944	914
TOTAL OPERATING EXPENSES	1,889	1,823	3,880	4,149
OPERATING INCOME	392	460	1,033	1,143
OTHER INCOME (DEDUCTIONS)
Investment and other income	1	2	2	3
Allowance for equity funds used during construction	2	1	4	2
Other deductions	(1)	(5)	(6)	(6)
TOTAL OTHER INCOME (DEDUCTIONS)	2	(2)	0	(1)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	394	458	1,033	1,142
INTEREST EXPENSE
Interest on long-term debt	146	141	290	282
Other interest	4	5	9	9
Allowance for borrowed funds used during construction	(1)	0	(2)	(1)
NET INTEREST EXPENSE	149	146	297	290
INCOME BEFORE INCOME TAX EXPENSE	245	312	736	852
INCOME TAX EXPENSE	84	101	264	293
NET INCOME	$ 161	$ 211	$ 472	$ 559

Consolidated Statement of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
NET INCOME	$ 232	$ 219	$ 542	$ 589
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	1	1	6
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	1	6
COMPREHENSIVE INCOME	233	220	543	595
CECONY
NET INCOME	161	211	472	559
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	1	1	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	1	1
COMPREHENSIVE INCOME	$ 162	$ 212	$ 473	$ 560

Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
OPERATING ACTIVITIES
NET INCOME	$ 542	$ 589
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	599	555
Deferred income taxes	268	202
Rate case amortization and accruals	(112)	(20)
Common equity component of allowance for funds used during construction	(4)	(2)
Net derivative (gains)/losses	(33)	8
Other non-cash items, net	42	18
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	101	35
Materials and supplies, including fuel oil and gas in storage	29	48
Other receivables and other current assets	(38)	(17)
Income taxes receivable	151	224
Prepayments	(15)	(144)
Accounts payable	(21)	(158)
Pensions and retiree benefits obligations, net	302	379
Pensions and retiree benefits contributions	(307)	(407)
Accrued taxes	(16)	(20)
Accrued interest	3	(1)
Superfund and environmental remediation costs, net	60	15
Distributions from equity investments	24	18
Deferred charges, noncurrent assets and other regulatory assets	(98)	(3)
Deferred credits and other regulatory liabilities	75	136
Other current and noncurrent liabilities	79	31
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,631	1,486
INVESTING ACTIVITIES
Utility construction expenditures	(1,344)	(1,174)
Cost of removal less salvage	(95)	(105)
Non-utility construction expenditures	(331)	(178)
Investments in/acquisitions of renewable electric production and electric and gas transmission projects	(1,250)	(252)
Proceeds from the transfer of assets to NY Transco	122	0
Restricted cash	(6)	(22)
Other investing activities	(82)	6
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,986)	(1,725)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(821)	445
Issuance of long-term debt	1,765	238
Retirement of long-term debt	(6)	(45)
Debt issuance costs	(15)	(2)
Common stock dividends	(378)	(380)
Issuance of common shares - public offering	702	0
Issuance of common shares for stock plans, net of repurchases	27	(7)
Distribution to noncontrolling interest	(1)	0
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,273	249
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(82)	10
BALANCE AT BEGINNING OF PERIOD	944	699
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	862	709
Cash paid/(received) during the period for:
Interest	318	305
Income taxes	(142)	(9)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	254	213
Issuance of common shares for dividend reinvestment	23	5
CECONY
OPERATING ACTIVITIES
NET INCOME	472	559
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	547	511
Deferred income taxes	283	135
Rate case amortization and accruals	(120)	(32)
Common equity component of allowance for funds used during construction	(4)	(2)
Other non-cash items, net	15	(10)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	102	53
Materials and supplies, including fuel oil and gas in storage	18	42
Other receivables and other current assets	(64)	11
Accounts receivable from affiliated companies	92	(4)
Prepayments	3	18
Accounts payable	(54)	(106)
Accounts payable to affiliated companies	5	5
Pensions and retiree benefits obligations, net	287	360
Pensions and retiree benefits contributions	(306)	(406)
Accrued taxes	(15)	(1)
Accrued interest	(3)	(1)
Superfund and environmental remediation costs, net	67	14
Accrued taxes to affiliated companies	(2)	(10)
Deferred charges, noncurrent assets and other regulatory assets	(100)	(22)
Deferred credits and other regulatory liabilities	89	119
Other current and noncurrent liabilities	87	(31)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,399	1,202
INVESTING ACTIVITIES
Utility construction expenditures	(1,268)	(1,108)
Cost of removal less salvage	(92)	(101)
Proceeds from the transfer of assets to NY Transco	122	0
Restricted cash	13	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,225)	(1,209)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(425)	545
Issuance of long-term debt	550	0
Debt issuance costs	(6)	(1)
Capital contribution by parent	51	0
Dividend to parent	(372)	(516)
NET CASH FLOWS FROM FINANCING ACTIVITIES	(202)	28
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(28)	21
BALANCE AT BEGINNING OF PERIOD	843	645
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	815	666
Cash paid/(received) during the period for:
Interest	285	277
Income taxes	(117)	160
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$ 196	$ 151

Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
CURRENT ASSETS
Cash and temporary cash investments	$ 862	$ 944
Special deposits	10	3
Accounts receivable - customers, less allowance for uncollectible accounts	951	1,052
Other receivables, less allowance for uncollectible accounts	247	304
Income taxes receivable	15	166
Accrued unbilled revenue	365	360
Fuel oil, gas in storage, materials and supplies, at average cost	321	350
Prepayments	192	177
Regulatory assets	84	132
Assets held for sale	183	157
Other current assets	269	191
TOTAL CURRENT ASSETS	3,499	3,836
INVESTMENTS	1,913	884
UTILITY PLANT, AT ORIGINAL COST
General	2,614	2,622
TOTAL	39,045	38,174
Less: Accumulated depreciation	8,305	8,044
Net	30,740	30,130
Construction work in progress	1,148	1,003
NET UTILITY PLANT	31,888	31,133
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	859	832
Construction work in progress	712	244
NET PLANT	33,459	32,209
OTHER NONCURRENT ASSETS
Goodwill	429	429
Intangible assets, less accumulated amortization of $5 and $4 in 2016 and 2015, respectively	2	2
Regulatory assets	7,680	8,096
Other deferred charges and noncurrent assets	288	186
TOTAL OTHER NONCURRENT ASSETS	8,399	8,713
TOTAL ASSETS	47,270	45,642
CURRENT LIABILITIES
Long-term debt due within one year	746	739
Notes payable	708	1,529
Accounts payable	969	1,008
Customer deposits	358	354
Accrued taxes	46	62
Accrued interest	139	136
Accrued wages	99	97
Fair value of derivative liabilities	62	66
Regulatory liabilities	122	115
Liabilities held for sale	60	89
Other current liabilities	594	525
TOTAL CURRENT LIABILITIES	3,903	4,720
NONCURRENT LIABILITIES
Provision for injuries and damages	188	185
Pensions and retiree benefits	2,423	2,911
Superfund and other environmental costs	758	765
Asset retirement obligations	249	242
Fair value of derivative liabilities	33	39
Deferred income taxes and unamortized investment tax credits	9,878	9,537
Regulatory liabilities	1,932	1,977
Other deferred credits and noncurrent liabilities	201	199
TOTAL NONCURRENT LIABILITIES	15,662	15,855
LONG-TERM DEBT	13,747	12,006
EQUITY
Common shareholders’ equity	13,950	13,052
Noncontrolling interest	8	9
TOTAL EQUITY (See Statement of Equity)	13,958	13,061
TOTAL LIABILITIES AND EQUITY	47,270	45,642
CECONY
CURRENT ASSETS
Cash and temporary cash investments	815	843
Special deposits	2	2
Accounts receivable - customers, less allowance for uncollectible accounts	890	987
Other receivables, less allowance for uncollectible accounts	76	70
Accrued unbilled revenue	328	327
Accounts receivable from affiliated companies	98	190
Fuel oil, gas in storage, materials and supplies, at average cost	270	288
Prepayments	110	113
Regulatory assets	77	121
Other current assets	165	131
TOTAL CURRENT ASSETS	2,831	3,072
INVESTMENTS	307	286
UTILITY PLANT, AT ORIGINAL COST
General	2,399	2,411
TOTAL	36,586	35,766
Less: Accumulated depreciation	7,615	7,378
Net	28,971	28,388
Construction work in progress	1,055	922
NET UTILITY PLANT	30,026	29,310
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	4	5
NET PLANT	30,030	29,315
OTHER NONCURRENT ASSETS
Regulatory assets	7,109	7,482
Other deferred charges and noncurrent assets	76	75
TOTAL OTHER NONCURRENT ASSETS	7,185	7,557
TOTAL ASSETS	40,353	40,230
CURRENT LIABILITIES
Long-term debt due within one year	650	650
Notes payable	608	1,033
Accounts payable	703	771
Accounts payable to affiliated companies	17	12
Customer deposits	343	339
Accrued taxes	34	49
Accrued taxes to affiliated companies	0	2
Accrued interest	115	118
Accrued wages	90	88
Fair value of derivative liabilities	44	50
Regulatory liabilities	98	84
Other current liabilities	516	443
TOTAL CURRENT LIABILITIES	3,218	3,639
NONCURRENT LIABILITIES
Provision for injuries and damages	181	178
Pensions and retiree benefits	2,085	2,565
Superfund and other environmental costs	664	665
Asset retirement obligations	238	234
Fair value of derivative liabilities	30	36
Deferred income taxes and unamortized investment tax credits	9,121	8,755
Regulatory liabilities	1,743	1,789
Other deferred credits and noncurrent liabilities	174	167
TOTAL NONCURRENT LIABILITIES	14,236	14,389
LONG-TERM DEBT	11,333	10,787
EQUITY
Common shareholders’ equity	11,566	11,415
TOTAL LIABILITIES AND EQUITY	40,353	40,230
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	26,961	26,358
Electric \| CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	25,398	24,828
OTHER NONCURRENT ASSETS
TOTAL ASSETS	30,632
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	7,102	6,858
Gas \| CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	6,421	6,191
OTHER NONCURRENT ASSETS
TOTAL ASSETS	7,131
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,368	2,336
Steam \| CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,368	$ 2,336
OTHER NONCURRENT ASSETS
TOTAL ASSETS	$ 2,590

Consolidated Balance Sheet (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Accounts receivable - customers, allowance for uncollectible accounts	$ 80	$ 85
Other receivables, allowance for uncollectible accounts	15	11
Non-utility property, accumulated depreciation	114	95
Intangible assets, accumulated amortization	5	4
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	75	80
Other receivables, allowance for uncollectible accounts	14	11
Non-utility property, accumulated depreciation	$ 25	$ 25

Consolidated Statement of Equity/Shareholder's Equity (Unaudited) - USD ($) $ in Millions	Total	CECONY	Common Stock	Common Stock CECONY	Additional Paid-In Capital	Additional Paid-In Capital CECONY	Retained Earnings	Retained Earnings CECONY	Repurchased Con Edison Stock CECONY	Treasury Stock	Capital Stock Expense	Capital Stock Expense CECONY	Accumulated Other Comprehensive Income/(Loss)	Accumulated Other Comprehensive Income/(Loss) CECONY	Noncontrolling Interest
Beginning Balance at Dec. 31, 2014	$ 12,585		$ 32		$ 4,991		$ 8,691			$ (1,032)	$ (61)		$ (45)	$ (11)	$ 9
Beginning Balance at Dec. 31, 2014		$ 11,188		$ 589		$ 4,234		$ 7,399	$ (962)			$ (61)		(11)
Beginning Balance (in shares) at Dec. 31, 2014			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	370	348					370	348
Common stock dividends	(190)	(338)					(190)	(338)
Issuance of common shares for stock plans, net of repurchases					2					$ (2)
Other comprehensive income	5	0											5	0
Ending Balance at Mar. 31, 2015		11,198		$ 589		4,234		7,409	(962)			(61)		(11)
Ending Balance at Mar. 31, 2015	12,770		$ 32		4,993		8,871			$ (1,034)	(61)		(40)	(11)	9
Ending Balance (in shares) at Mar. 31, 2015			293,000,000	235,000,000						23,000,000
Beginning Balance at Dec. 31, 2014	12,585		$ 32		4,991		8,691			$ (1,032)	(61)		(45)	(11)	9
Beginning Balance at Dec. 31, 2014		11,188		$ 589		4,234		7,399	(962)			(61)		(11)
Beginning Balance (in shares) at Dec. 31, 2014			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	589	559
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)	(10)	9
Ending Balance (in shares) at Jun. 30, 2015			293,000,000	235,000,000						23,000,000
Beginning Balance at Mar. 31, 2015	12,770		$ 32		4,993		8,871			$ (1,034)	(61)		(40)	(11)	9
Beginning Balance at Mar. 31, 2015		11,198		$ 589		4,234		7,409	(962)			(61)		(11)
Beginning Balance (in shares) at Mar. 31, 2015			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	219	211					219	211
Common stock dividends	(190)	(178)					(190)	(178)
Issuance of common shares for stock plans, net of repurchases	(3)									$ (3)
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)	(10)	9
Ending Balance (in shares) at Jun. 30, 2015			293,000,000	235,000,000						23,000,000
Beginning Balance at Dec. 31, 2015	13,061		$ 32		5,030		9,123			$ (1,038)	(61)		(34)	(9)	9
Beginning Balance at Dec. 31, 2015	13,052	11,415		$ 589		4,247		7,611	(962)			(61)		(9)
Beginning Balance (in shares) at Dec. 31, 2015			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	310	310					310	310
Common stock dividends	(197)	(186)					(197)	(186)
Issuance of common shares for stock plans, net of repurchases	28				28
Issuance of common shares for stock plans, net of repurchases (in shares)			1,000,000
Capital contribution by parent		23				23
Other comprehensive income	0	0											0	0
Noncontrolling interest	(1)														(1)
Ending Balance at Mar. 31, 2016		11,562		$ 589		4,270		7,735	(962)			(61)		(9)
Ending Balance at Mar. 31, 2016	13,201		$ 32		5,058		9,236			$ (1,038)	(61)		(34)	(9)	8
Ending Balance (in shares) at Mar. 31, 2016			294,000,000	235,000,000						23,000,000
Beginning Balance at Dec. 31, 2015	13,061		$ 32		5,030		9,123			$ (1,038)	(61)		(34)	(9)	9
Beginning Balance at Dec. 31, 2015	13,052	11,415		$ 589		4,247		7,611	(962)			(61)		(9)
Beginning Balance (in shares) at Dec. 31, 2015			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	542	472
Ending Balance at Jun. 30, 2016	13,950	11,566		$ 589		4,298		7,710	(962)			(61)		(8)
Ending Balance at Jun. 30, 2016	13,958		$ 33		5,807		9,264			$ (1,038)	(83)		(33)	(8)	8
Ending Balance (in shares) at Jun. 30, 2016			304,000,000	235,000,000						23,000,000
Beginning Balance at Mar. 31, 2016	13,201		$ 32		5,058		9,236			$ (1,038)	(61)		(34)	(9)	8
Beginning Balance at Mar. 31, 2016		11,562		$ 589		4,270		7,735	(962)			(61)		(9)
Beginning Balance (in shares) at Mar. 31, 2016			294,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	232	161					232	161
Common stock dividends	(204)	(186)					(204)	(186)
Issuance of common shares - public offering	702		$ 1		723						(22)
Issuance of common shares - public offering (in shares)			10,000,000
Issuance of common shares for stock plans, net of repurchases	26				26
Capital contribution by parent		28				28
Other comprehensive income	1	1											1	1
Ending Balance at Jun. 30, 2016	13,950	$ 11,566		$ 589		$ 4,298		$ 7,710	$ (962)			$ (61)		(8)
Ending Balance at Jun. 30, 2016	$ 13,958		$ 33		$ 5,807		$ 9,264			$ (1,038)	$ (83)		$ (33)	$ (8)	$ 8
Ending Balance (in shares) at Jun. 30, 2016			304,000,000	235,000,000						23,000,000

General	6 Months Ended
General	Jun. 30, 2016
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), Con Edison Transmission, Inc. (Con Edison Transmission) and Con Edison’s competitive energy businesses 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, 2015 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016. 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 P) 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 P), 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, Con Edison has a subsidiary, Con Edison Transmission, that invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas).
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), Con Edison Transmission, Inc. (Con Edison Transmission) and Con Edison’s competitive energy businesses 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, 2015 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016. 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 P) 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 P), 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, Con Edison has a subsidiary, Con Edison Transmission, that invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas).

Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2016

Summary of Significant Accounting Policies

Earnings Per Common Share

For the three and six months ended June 30, 2016 and 2015, basic and diluted earnings per share (EPS) for Con Edison are calculated as follows:



	For the Three Months Ended June 30,		For the Six Months Ended June 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2016	2015
Net income	$232	$219	$542	$589
Weighted average common shares outstanding – basic	299.1	292.9	296.7	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.3	1.1	1.3	1.0
Adjusted weighted average common shares outstanding – diluted	300.4	294.0	298.0	293.9
Net income per common share – basic	$0.78	$0.75	$1.83	$2.01
Net income per common share – diluted	$0.77	$0.74	$1.82	$2.01

The computation of diluted EPS for the six months ended June 30, 2016 and three and six months ended June 30, 2015 excludes immaterial amounts of stock-based compensation awards that were not included because of their anti-dilutive effect.

Changes in Accumulated Other Comprehensive Income/(Loss) by Component

For the three and six months ended June 30, 2016 and 2015, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(40)	$(9)	$(11)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015 (a)(b)	1	1	1	1
Current period OCI, net of taxes	1	1	1	1
Ending balance, accumulated OCI, net of taxes	$(33)	$(39)	$(8)	$(10)



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(45)	$(9)	$(11)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively	(1)	3	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2016 and 2015 (a)(b)	2	3	1	1
Current period OCI, net of taxes	1	6	1	1
Ending balance, accumulated OCI, net of taxes	$(33)	$(39)	$(8)	$(10)


(a)	Tax reclassified from accumulated OCI is reported in the income tax expense line item of the consolidated income statement.


(b)	For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets 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

Earnings Per Common Share

For the three and six months ended June 30, 2016 and 2015, basic and diluted earnings per share (EPS) for Con Edison are calculated as follows:



	For the Three Months Ended June 30,		For the Six Months Ended June 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2016	2015
Net income	$232	$219	$542	$589
Weighted average common shares outstanding – basic	299.1	292.9	296.7	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.3	1.1	1.3	1.0
Adjusted weighted average common shares outstanding – diluted	300.4	294.0	298.0	293.9
Net income per common share – basic	$0.78	$0.75	$1.83	$2.01
Net income per common share – diluted	$0.77	$0.74	$1.82	$2.01

Changes in Accumulated Other Comprehensive Income/(Loss) by Component

For the three and six months ended June 30, 2016 and 2015, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(40)	$(9)	$(11)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015 (a)(b)	1	1	1	1
Current period OCI, net of taxes	1	1	1	1
Ending balance, accumulated OCI, net of taxes	$(33)	$(39)	$(8)	$(10)



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(45)	$(9)	$(11)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively	(1)	3	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2016 and 2015 (a)(b)	2	3	1	1
Current period OCI, net of taxes	1	6	1	1
Ending balance, accumulated OCI, net of taxes	$(33)	$(39)	$(8)	$(10)


(a)	Tax reclassified from accumulated OCI is reported in the income tax expense line item of the consolidated income statement.


(b)	For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets 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

6 Months Ended

Jun. 30, 2016

Public Utilities, General Disclosures [Line Items]

Regulatory Matters

Rate Plans

CECONY - Electric

In May 2016, the New York State Public Service Commission (NYSPSC) staff submitted testimony in the NYSPSC January 2016 proceeding in which CECONY requested an electric rate increase, effective January 2017. The NYSPSC staff testimony supports an electric rate increase of $45 million reflecting, among other things, an 8.6 percent return on common equity. In June 2016, CECONY filed an update to its January 2016 request. The company increased its requested January 2017 rate increase by $16 million to $498 million, decreased its illustrated January 2018 rate increase by $11 million to $169 million and increased its illustrated January 2019 rate increase by $45 million to $186 million. This updated filing reflects a 9.75 percent return on common equity.

In April 2016, the Federal Energy Regulatory Commission (FERC) rejected CECONY’s challenge to FERC’s approval of substantially increased charges allocated to CECONY for transmission service provided pursuant to the open access tariff of PJM Interconnection LLC (PJM). CECONY will continue to challenge FERC’s approval of the increased charges that will be incurred over the remaining contract term, and in May 2016 filed an appeal of FERC's decision with the U.S. Court of Appeals. In April 2016, CECONY notified PJM that it will not be exercising its option to continue the service beyond April 2017.

CECONY - Gas

In May 2016, the NYSPSC staff submitted testimony in the NYSPSC January 2016 proceeding in which CECONY requested a gas rate increase, effective January 2017. The NYSPSC staff testimony supports a gas rate decrease of $25 million reflecting, among other things, an 8.6 percent return on common equity. In June 2016, CECONY filed an update to its January 2016 request. The company decreased its requested January 2017 rate increase by $29 million to $125 million, increased its illustrated January 2018 rate increase by $13 million to $110 million and decreased its illustrated January 2019 rate increase by $9 million to $100 million. This updated filing reflects a 9.75 percent return on common equity.

Rockland Electric Company (RECO)

In April 2016, RECO filed a request with the New Jersey Board of Public Utilities for an electric rate increase of $10 million, effective March 2017. The filing reflected a return on common equity of 10.20 percent and a common equity ratio of 49.81 percent. In July 2016, RECO filed an update to its April 2016 request. The company decreased its requested March 2017 rate increase by $1 million to $9 million. The updated filing reflects a return on common equity of 10.20 percent and a common equity ratio of 49.71 percent. The filing reflects continuation of provisions pursuant to which the company recovers its purchased power and fuel costs from customers.

Other Regulatory Matters

In April 2016, the NYSPSC approved the September 2015 Joint Proposal among CECONY, the NYSPSC staff and others with respect to the prudence proceeding the NYSPSC commenced in February 2009 and related matters. 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 are no longer subject to refund. At June 30, 2016, the company had a $97 million regulatory liability for the remaining amount to be credited to customers related to this matter.

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 December 2015, the NYSPSC staff informed O&R that the company had satisfactorily completed its risk assessment and remediation plan. CECONY expects to submit its risk assessment and remediation plan to the NYSPSC staff in 2016.

In November 2015, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence proceedings to penalize the company for alleged violations of gas safety regulations identified by the NYSPSC staff in its investigation of a March 2014 explosion and fire and to review the prudence of the company's conduct associated with the incident. See "Manhattan Explosion and Fire" in Note H. In December 2015, the company responded that the NYSPSC should not institute the proceedings and disputed the alleged violations.

At June 30, 2016, CECONY had an $18 million regulatory liability related to the June 2014 plastic fusion proceeding and the November 2015 order to show cause. The company is unable to estimate the amount or range of its possible loss related to these matters in excess of this regulatory liability.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at June 30, 2016 and December 31, 2015 were comprised of the following items:



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$3,516	$3,876	$3,361	$3,697
Future income tax	2,379	2,350	2,262	2,232
Environmental remediation costs	837	904	732	800
Revenue taxes	295	253	281	240
Deferred storm costs	122	185	57	110
Unamortized loss on reacquired debt	47	50	44	48
O&R property tax reconciliation	42	46	—	—
Deferred derivative losses	38	50	35	46
Pension and other postretirement benefits deferrals	35	45	6	16
Net electric deferrals	34	44	34	44
Surcharge for New York State assessment	32	44	29	40
Preferred stock redemption	26	26	26	26
O&R transition bond charges	18	21	—	—
Workers’ compensation	16	11	16	11
Recoverable energy costs	—	16	—	15
Other	243	175	226	157
Regulatory assets – noncurrent	7,680	8,096	7,109	7,482
Deferred derivative losses	75	113	70	103
Recoverable energy costs	9	19	7	18
Regulatory assets – current	84	132	77	121
Total Regulatory Assets	$7,764	$8,228	$7,186	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$708	$676	$599	$570
Property tax reconciliation	230	303	230	303
Pension and other postretirement benefit deferrals	125	76	96	46
Net unbilled revenue deferrals	117	109	117	109
Prudence proceeding	97	99	97	99
Unrecognized other postretirement costs	93	28	93	28
Base rate change deferrals	77	128	77	128
New York State income tax rate change	69	75	66	72
Variable-rate tax-exempt debt – cost rate reconciliation	64	70	56	60
Carrying charges on repair allowance and bonus depreciation	51	49	50	48
Earnings sharing - electric, gas and steam	34	80	30	80
Net utility plant reconciliations	28	32	28	31
Property tax refunds	22	44	22	44
World Trade Center settlement proceeds	10	21	10	21
Other	207	187	172	150
Regulatory liabilities – noncurrent	1,932	1,977	1,743	1,789
Revenue decoupling mechanism	79	45	78	45
Refundable energy costs	30	64	9	33
Deferred derivative gains	13	6	11	6
Regulatory liabilities – current	122	115	98	84
Total Regulatory Liabilities	$2,054	$2,092	$1,841	$1,873

CECONY

Public Utilities, General Disclosures [Line Items]

Regulatory Matters

Rate Plans

CECONY - Electric

CECONY - Gas

Rockland Electric Company (RECO)

Other Regulatory Matters

Regulatory Assets and Liabilities

Regulatory assets and liabilities at June 30, 2016 and December 31, 2015 were comprised of the following items:



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$3,516	$3,876	$3,361	$3,697
Future income tax	2,379	2,350	2,262	2,232
Environmental remediation costs	837	904	732	800
Revenue taxes	295	253	281	240
Deferred storm costs	122	185	57	110
Unamortized loss on reacquired debt	47	50	44	48
O&R property tax reconciliation	42	46	—	—
Deferred derivative losses	38	50	35	46
Pension and other postretirement benefits deferrals	35	45	6	16
Net electric deferrals	34	44	34	44
Surcharge for New York State assessment	32	44	29	40
Preferred stock redemption	26	26	26	26
O&R transition bond charges	18	21	—	—
Workers’ compensation	16	11	16	11
Recoverable energy costs	—	16	—	15
Other	243	175	226	157
Regulatory assets – noncurrent	7,680	8,096	7,109	7,482
Deferred derivative losses	75	113	70	103
Recoverable energy costs	9	19	7	18
Regulatory assets – current	84	132	77	121
Total Regulatory Assets	$7,764	$8,228	$7,186	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$708	$676	$599	$570
Property tax reconciliation	230	303	230	303
Pension and other postretirement benefit deferrals	125	76	96	46
Net unbilled revenue deferrals	117	109	117	109
Prudence proceeding	97	99	97	99
Unrecognized other postretirement costs	93	28	93	28
Base rate change deferrals	77	128	77	128
New York State income tax rate change	69	75	66	72
Variable-rate tax-exempt debt – cost rate reconciliation	64	70	56	60
Carrying charges on repair allowance and bonus depreciation	51	49	50	48
Earnings sharing - electric, gas and steam	34	80	30	80
Net utility plant reconciliations	28	32	28	31
Property tax refunds	22	44	22	44
World Trade Center settlement proceeds	10	21	10	21
Other	207	187	172	150
Regulatory liabilities – noncurrent	1,932	1,977	1,743	1,789
Revenue decoupling mechanism	79	45	78	45
Refundable energy costs	30	64	9	33
Deferred derivative gains	13	6	11	6
Regulatory liabilities – current	122	115	98	84
Total Regulatory Liabilities	$2,054	$2,092	$1,841	$1,873

Capitalization

6 Months Ended

Jun. 30, 2016

Debt Instrument [Line Items]

Capitalization

In February 2016, a Con Edison Development subsidiary issued $218 million aggregate principal amount of 4.21 percent senior notes, due 2041, secured by the company's Texas Solar 7 solar project.

In May 2016, Con Edison issued approximately 10 million common shares resulting in net proceeds, after issuance expenses, of $702 million, and $500 million aggregate principal amount of 2.00 percent debentures, due 2021. Also, in May 2016, a Con Edison Development subsidiary issued $95 million aggregate principal amount of 4.07 percent senior notes, due 2036, secured by the company's California Holding 3 solar projects. In June 2016, Con Edison borrowed $400 million pursuant to a credit agreement with a syndicate of banks. The borrowing matures in 2018 and bears interest at a LIBOR plus margin of 1.00 percent. In June 2016, CECONY issued $550 million aggregate principal amount of 3.85 percent debentures, due 2046. Also, in June 2016, a Con Edison Solutions subsidiary borrowed $2 million pursuant to a loan agreement with a New Jersey utility. The borrowing matures in 2026, bears interest of 11.18 percent and may be repaid in cash or project Solar Renewable Energy Certificates.

The carrying amounts and fair values of long-term debt at June 30, 2016 and December 31, 2015 were:



(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,493	$16,681	$12,745	$13,856
CECONY	$11,983	$13,917	$11,437	$12,427

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $16,045 million and $636 million of the fair value of long-term debt at June 30, 2016 are classified as Level 2 and Level 3, respectively. For CECONY, $13,281 million and $636 million of the fair value of long-term debt at June 30, 2016 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

In February 2016, a Con Edison Development subsidiary issued $218 million aggregate principal amount of 4.21 percent senior notes, due 2041, secured by the company's Texas Solar 7 solar project.

The carrying amounts and fair values of long-term debt at June 30, 2016 and December 31, 2015 were:



(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,493	$16,681	$12,745	$13,856
CECONY	$11,983	$13,917	$11,437	$12,427

Short-Term Borrowing	6 Months Ended
Short-Term Borrowing	Jun. 30, 2016
Short-Term Borrowing	Short-Term Borrowing At June 30, 2016, Con Edison had $708 million of commercial paper outstanding of which $608 million was outstanding under CECONY’s program. The weighted average interest rate at June 30, 2016 was 0.7 percent for both Con Edison and CECONY. At December 31, 2015, Con Edison had $1,529 million of commercial paper outstanding of which $1,033 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2015 was 0.7 percent for both Con Edison and CECONY. At June 30, 2016 and December 31, 2015, no loans were outstanding under the credit agreement (Credit Agreement) and $2 million (including $2 million for CECONY) and $15 million of letters of credit were outstanding under the Credit Agreement, respectively.
CECONY
Short-Term Borrowing	Short-Term Borrowing At June 30, 2016, Con Edison had $708 million of commercial paper outstanding of which $608 million was outstanding under CECONY’s program. The weighted average interest rate at June 30, 2016 was 0.7 percent for both Con Edison and CECONY. At December 31, 2015, Con Edison had $1,529 million of commercial paper outstanding of which $1,033 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2015 was 0.7 percent for both Con Edison and CECONY. At June 30, 2016 and December 31, 2015, no loans were outstanding under the credit agreement (Credit Agreement) and $2 million (including $2 million for CECONY) and $15 million of letters of credit were outstanding under the Credit Agreement, respectively.

Pension Benefits

6 Months Ended

Jun. 30, 2016

Defined Benefit Plan Disclosure [Line Items]

Pension Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit costs for the three and six months ended June 30, 2016 and 2015 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$69	$74	$65	$70
Interest cost on projected benefit obligation	149	144	140	135
Expected return on plan assets	(237)	(222)	(225)	(210)
Recognition of net actuarial loss	149	194	141	183
Recognition of prior service costs	1	1	—	—
NET PERIODIC BENEFIT COST	$131	$191	$121	$178
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$131	$192	$121	$179
Cost capitalized	(53)	(76)	(50)	(72)
Reconciliation to rate level	13	(17)	14	(18)
Cost charged to operating expenses	$91	$99	$85	$89



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$138	$149	$129	$139
Interest cost on projected benefit obligation	298	287	280	269
Expected return on plan assets	(474)	(443)	(449)	(420)
Recognition of net actuarial loss	298	388	282	367
Recognition of prior service costs	2	2	1	1
NET PERIODIC BENEFIT COST	$262	$383	$243	$356
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$262	$384	$243	$357
Cost capitalized	(106)	(144)	(99)	(137)
Reconciliation to rate level	26	(42)	26	(42)
Cost charged to operating expenses	$182	$198	$170	$178

Expected Contributions

Based on estimates as of June 30, 2016, the Companies expect to make contributions to the pension plans during 2016 of $508 million (of which $469 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 six months of 2016, the Companies contributed $307 million to the pension plans, nearly all of which was contributed by CECONY. CECONY also contributed $17 million to its external trust for supplemental plans.

CECONY

Defined Benefit Plan Disclosure [Line Items]

Pension Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit costs for the three and six months ended June 30, 2016 and 2015 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$69	$74	$65	$70
Interest cost on projected benefit obligation	149	144	140	135
Expected return on plan assets	(237)	(222)	(225)	(210)
Recognition of net actuarial loss	149	194	141	183
Recognition of prior service costs	1	1	—	—
NET PERIODIC BENEFIT COST	$131	$191	$121	$178
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$131	$192	$121	$179
Cost capitalized	(53)	(76)	(50)	(72)
Reconciliation to rate level	13	(17)	14	(18)
Cost charged to operating expenses	$91	$99	$85	$89



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$138	$149	$129	$139
Interest cost on projected benefit obligation	298	287	280	269
Expected return on plan assets	(474)	(443)	(449)	(420)
Recognition of net actuarial loss	298	388	282	367
Recognition of prior service costs	2	2	1	1
NET PERIODIC BENEFIT COST	$262	$383	$243	$356
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$262	$384	$243	$357
Cost capitalized	(106)	(144)	(99)	(137)
Reconciliation to rate level	26	(42)	26	(42)
Cost charged to operating expenses	$182	$198	$170	$178

Expected Contributions

Other Postretirement Benefits

6 Months Ended

Jun. 30, 2016

Defined Benefit Plan Disclosure [Line Items]

Other Postretirement Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic other postretirement benefit costs for the three and six months ended June 30, 2016 and 2015 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost	$4	$5	$3	$4
Interest cost on accumulated other postretirement benefit obligation	12	13	10	11
Expected return on plan assets	(19)	(20)	(17)	(17)
Recognition of net actuarial loss	1	8	1	7
Recognition of prior service cost	(5)	(5)	(3)	(4)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(7)	$1	$(6)	$1
Cost capitalized	2	(1)	2	(1)
Reconciliation to rate level	7	4	6	2
Cost charged to operating expenses	$2	$4	$2	$2



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost	$9	$10	$7	$7
Interest cost on accumulated other postretirement benefit obligation	24	25	20	22
Expected return on plan assets	(38)	(39)	(34)	(34)
Recognition of net actuarial loss	2	16	1	14
Recognition of prior service cost	(10)	(10)	(7)	(7)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(13)	$2	$(13)	$2
Cost capitalized	3	(1)	3	(1)
Reconciliation to rate level	14	8	14	3
Cost charged to operating expenses	$4	$9	$4	$4

Expected Contributions

Environmental Matters

6 Months Ended

Jun. 30, 2016

Site Contingency [Line Items]

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 June 30, 2016 and December 31, 2015 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$670	$679	$576	$579
Other Superfund Sites	88	86	88	86
Total	$758	$765	$664	$665
Regulatory assets	$837	$904	$732	$800

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 related to Superfund Sites for the three and six months ended June 30, 2016 and 2015 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$9	$8	$3	$7



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$12	$15	$5	$12

No insurance recoveries were received by Con Edison or CECONY for the three or six months ended June 30, 2016 and 2015.

In 2015, 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 $2.8 billion and $2.7 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 June 30, 2016, 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 as shown in the following table. 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 June 30, 2016 and December 31, 2015 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$91	$86	$86	$81
Regulatory assets – workers’ compensation	$16	$11	$16	$11

CECONY

Site Contingency [Line Items]

Environmental Matters

Superfund Sites

The accrued liabilities and regulatory assets related to Superfund Sites at June 30, 2016 and December 31, 2015 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$670	$679	$576	$579
Other Superfund Sites	88	86	88	86
Total	$758	$765	$664	$665
Regulatory assets	$837	$904	$732	$800

Environmental remediation costs incurred related to Superfund Sites for the three and six months ended June 30, 2016 and 2015 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$9	$8	$3	$7



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$12	$15	$5	$12

No insurance recoveries were received by Con Edison or CECONY for the three or six months ended June 30, 2016 and 2015.

Asbestos Proceedings



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$91	$86	$86	$81
Regulatory assets – workers’ compensation	$16	$11	$16	$11

Other Material Contingencies

6 Months Ended

Jun. 30, 2016

Guarantor Obligations [Line Items]

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 eighty 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 June 30, 2016, 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 also conducted 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 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, 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 for damages related to the incident. At June 30, 2016, the company had not accrued a liability for damages related to 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 $2,544 million and $2,856 million at June 30, 2016 and December 31, 2015, respectively.

A summary, by type and term, of Con Edison’s total guarantees at June 30, 2016 is as follows:



Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$619	$583		$—	$1,202
Energy transactions	672	41	91		804
Renewable electric production projects	443	—	20		463
Other	75	—	—		75
Total	$1,809	$624	$111		$2,544

Con Edison Transmission — Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric acquired a 45.7 percent interest in NY Transco when it was formed in 2014. NY Transco’s transmission projects are expected to be initially developed by CECONY and other New York transmission owners and then transferred to NY Transco. In May 2016, the transmission owners transferred certain projects to NY Transco, as to which CET Electric made its required contributions. See Note Q. The other projects that were proposed when NY Transco was formed remain subject to certain authorizations from the NYSPSC, the FERC and, as applicable, other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of CET Electric’s contributions for these other projects as calculated based on the assumptions that the projects are completed at 175 percent of their estimated costs and NY Transco does not use any debt financing for the projects. Guarantee term shown is assumed as the timing of the contributions is not certain. Also included within the table above is a guarantee for $25 million from Con Edison on behalf of CET Gas in relation to a proposed gas transmission project in West Virginia and Virginia (see Note Q).

Energy Transactions — Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet.

Renewable Electric Production Projects — Con Edison, Con Edison Development, and Con Edison Solutions guarantee payments associated with the investment in solar and wind energy facilities on behalf of their wholly-owned subsidiaries.

Other — Other guarantees primarily relate to $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects and operation of solar energy facilities of Con Edison Solutions and Con Edison Development, respectively. In addition, Con Edison issued a guarantee estimated at $5 million to the Public Utility Commission of Texas covering obligations of Con Edison Solutions as a retail electric provider.

In addition to the guarantees included in the table above, in July 2016, Con Edison guaranteed (subject to a $53 million maximum amount) certain obligations of Con Edison Solutions under its agreement to sell the assets of its retail electric supply business to a subsidiary of Exelon Corporation. See Note P.

CECONY

Guarantor Obligations [Line Items]

Other Material Contingencies

Manhattan Steam Main Rupture

Manhattan Explosion and Fire

Other Contingencies

See “Other Regulatory Matters” in Note B and “Uncertain Tax Positions” in Note I.

Guarantees

A summary, by type and term, of Con Edison’s total guarantees at June 30, 2016 is as follows:



Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$619	$583		$—	$1,202
Energy transactions	672	41	91		804
Renewable electric production projects	443	—	20		463
Other	75	—	—		75
Total	$1,809	$624	$111		$2,544

Income Tax	6 Months Ended
Income Tax	Jun. 30, 2016
Income Tax Examination [Line Items]
Income Tax	Income Tax Con Edison’s income tax expense increased to $124 million for the three months ended June 30, 2016 from $101 million for the three months ended June 30, 2015. Con Edison's effective tax rate for the three months ended June 30, 2016 and 2015 was 35 percent and 32 percent, respectively. For the three months ended June 30, 2016, Con Edison recorded lower tax benefits for plant-related flow through items, partially offset by increased tax benefits as a result of higher injuries and damages payments and higher renewable energy tax credits. CECONY’s income tax expense decreased to $84 million for the three months ended June 30, 2016 from $101 million for the three months ended June 30, 2015. CECONY's effective tax rate for the three months ended June 30, 2016 and 2015 was 34 percent and 32 percent, respectively. The increase in CECONY's effective tax rate is primarily related to a decrease in tax benefits for plant-related flow through items, partially offset by increased tax benefits as a result of higher injuries and damages payments. Con Edison’s income tax expense decreased to $288 million for the six months ended June 30, 2016 from $300 million for the six months ended June 30, 2015. Con Edison's effective tax rate for the six months ended June 30, 2016 and 2015 was 35 percent and 34 percent, respectively. For the six months ended June 30, 2016, Con Edison recorded income tax benefits for research and development tax credits and higher renewable energy tax credits, which were primarily offset by a decrease in tax benefits for plant-related flow through items. CECONY’s income tax expense decreased to $264 million for the six months ended June 30, 2016 from $293 million for the six months ended June 30, 2015. CECONY's effective tax rate for the six months ended June 30, 2016 and 2015 was 36 percent and 34 percent, respectively. The increase in CECONY's effective tax rate is primarily related to a decrease in tax benefits for plant-related flow through items, partially offset by research and development tax credits. Con Edison anticipates a federal consolidated net operating loss for 2016, primarily due to bonus depreciation. Con Edison expects to carryback a portion of its 2016 net operating loss and recover $10 million of income tax. General business tax credits that became available as a result of the net operating loss carryback, as well as the remaining 2016 net operating loss will be carried forward to future tax years. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized. Uncertain Tax Positions At June 30, 2016, the estimated liability for uncertain tax positions for Con Edison was $36 million ($4 million for CECONY). Con Edison reasonably expects to resolve approximately $27 million ($18 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 $4 million ($3 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 $36 million ($24 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 six months ended June 30, 2016, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At June 30, 2016 and December 31, 2015, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.
CECONY
Income Tax Examination [Line Items]
Income Tax	Income Tax Con Edison’s income tax expense increased to $124 million for the three months ended June 30, 2016 from $101 million for the three months ended June 30, 2015. Con Edison's effective tax rate for the three months ended June 30, 2016 and 2015 was 35 percent and 32 percent, respectively. For the three months ended June 30, 2016, Con Edison recorded lower tax benefits for plant-related flow through items, partially offset by increased tax benefits as a result of higher injuries and damages payments and higher renewable energy tax credits. CECONY’s income tax expense decreased to $84 million for the three months ended June 30, 2016 from $101 million for the three months ended June 30, 2015. CECONY's effective tax rate for the three months ended June 30, 2016 and 2015 was 34 percent and 32 percent, respectively. The increase in CECONY's effective tax rate is primarily related to a decrease in tax benefits for plant-related flow through items, partially offset by increased tax benefits as a result of higher injuries and damages payments. Con Edison’s income tax expense decreased to $288 million for the six months ended June 30, 2016 from $300 million for the six months ended June 30, 2015. Con Edison's effective tax rate for the six months ended June 30, 2016 and 2015 was 35 percent and 34 percent, respectively. For the six months ended June 30, 2016, Con Edison recorded income tax benefits for research and development tax credits and higher renewable energy tax credits, which were primarily offset by a decrease in tax benefits for plant-related flow through items. CECONY’s income tax expense decreased to $264 million for the six months ended June 30, 2016 from $293 million for the six months ended June 30, 2015. CECONY's effective tax rate for the six months ended June 30, 2016 and 2015 was 36 percent and 34 percent, respectively. The increase in CECONY's effective tax rate is primarily related to a decrease in tax benefits for plant-related flow through items, partially offset by research and development tax credits. Con Edison anticipates a federal consolidated net operating loss for 2016, primarily due to bonus depreciation. Con Edison expects to carryback a portion of its 2016 net operating loss and recover $10 million of income tax. General business tax credits that became available as a result of the net operating loss carryback, as well as the remaining 2016 net operating loss will be carried forward to future tax years. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized. Uncertain Tax Positions At June 30, 2016, the estimated liability for uncertain tax positions for Con Edison was $36 million ($4 million for CECONY). Con Edison reasonably expects to resolve approximately $27 million ($18 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 $4 million ($3 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 $36 million ($24 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 six months ended June 30, 2016, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At June 30, 2016 and December 31, 2015, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

Financial Information by Business Segment

6 Months Ended

Jun. 30, 2016

Segment Reporting Information [Line Items]

Financial Information by Business Segment

In 2016, Con Edison Transmission began investing, through CET Electric and CET Gas, in electric transmission and gas pipeline and storage assets (see Note Q). As a result of these investments, Con Edison has changed its business segments to add Con Edison Transmission as a separate reportable segment based on management’s reporting and decision-making, including performance evaluation and resource allocation. For comparison purposes, the previously reported financial information by business segments was reclassified to reflect the current business segment presentation.

The financial data for the business segments are as follows:



	For the Three Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)				Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$1,892	$1,879	$4		$5		$215	$201	$371	$422	$2		$(1)		$113	$113	$88	$99	$30,632	$30,474	$338	$409
Gas	304	308	1		1		39	35	48	54	—		(1)		26	23	9	12	7,131	6,598	205	161
Steam	85	96	21		21		21	18	(27)	(16)	—		—		10	10	(10)	(6)	2,590	2,629	28	21
Consolidation adjustments	—	—	(26)		(27)		—	—	—	—	—		—		—	—	—	—	—	—	—	—
Total CECONY	$2,281	$2,283		$—		$—	$275	$254	$392	$460	$2		$(2)		$149	$146	$87	$105	$40,353	$39,701	$571	$591
O&R
Electric	$144	$162		$—		$—	$13	$13	$14	$16		$—		$—	$6	$5	$3	$4	$1,928	$1,944	$25	$25
Gas	31	16	—		—		4	4	(1)	(18)	—		—		3	4	(1)	(8)	761	739	12	11
Total O&R	$175	$178		$—		$—	$17	$17	$13	$(2)		$—		$—	$9	$9	$2	$(4)	$2,689	$2,683	$37	$36
Competitive energy businesses	$338	$328	$3		$(1)		$10	$6	$109	$13	$7		$12		$8	$2	$36	$7	$2,494	$1,549	$128	$364
Con Edison Transmission	—	—	—		—		—	—	(1)	—	3		—		1	—	—	—	1,043	2	—	—
Other (a)	—	(1)	(3)		1		—	(1)	2	1	(1)		—		3	5	3	—	691	816	—	—
Total Con Edison	$2,794	$2,788		$—		$—	$302	$276	$515	$472	$11		$10		$170	$162	$128	$108	$47,270	$44,751	$736	$991


(a)	Parent company and consolidation adjustments. Other does not represent a business segment.



	For the Six Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)			Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016		2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$3,665	$3,858	$9		$9		$428	$403	$645	$700	$1		$(1)	$225	$223	$137	$142	$30,632	$30,474	$720	$744
Gas	905	963	3		3		78	70	301	294	(1)		—	52	46	97	98	7,131	6,598	365	289
Steam	343	471	44		43		41	38	87	149	—		—	20	21	35	60	2,590	2,629	51	38
Consolidation adjustments	—	—	(56)		(55)		—	—	—	—	—		—	—	—	—	—	—	—	—	—
Total CECONY	$4,913	$5,292		$—		$—	$547	$511	$1,033	$1,143		$—	$(1)	$297	$290	$269	$300	$40,353	$39,701	$1,136	$1,071
O&R
Electric	$284	$318		$—		$—	$24	$25	$32	$34		$—	$1	$12	$11	$7	$9	$1,928	$1,944	$47	$45
Gas	106	93	—		—		9	9	34	9	—		—	6	6	12	1	761	739	21	17
Total O&R	$390	$411		$—		$—	$33	$34	$66	$43		$—	$1	$18	$17	$19	$10	$2,689	$2,683	$68	$62
Competitive energy businesses	$648	$702	$9		$(4)		$19	$11	$58	$10	$9		$15	$16	$3	$9	$4	$2,494	$1,549	$556	$464
Con Edison Transmission	—	—	—		—		—	—	(1)	—	3		—	1	—	—	—	1,043	2	—	—
Other (a)	(1)	(1)	(9)		4		—	(1)	1	2	—		(1)	7	13	2	—	691	816	—	—
Total Con Edison	$5,950	$6,404		$—		$—	$599	$555	$1,157	$1,198	$12		$14	$339	$323	$299	$314	$47,270	$44,751	$1,760	$1,597


(a)	Parent company and consolidation adjustments. Other does not represent a business segment.

CECONY

Segment Reporting Information [Line Items]

Financial Information by Business Segment

The financial data for the business segments are as follows:



	For the Three Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)				Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$1,892	$1,879	$4		$5		$215	$201	$371	$422	$2		$(1)		$113	$113	$88	$99	$30,632	$30,474	$338	$409
Gas	304	308	1		1		39	35	48	54	—		(1)		26	23	9	12	7,131	6,598	205	161
Steam	85	96	21		21		21	18	(27)	(16)	—		—		10	10	(10)	(6)	2,590	2,629	28	21
Consolidation adjustments	—	—	(26)		(27)		—	—	—	—	—		—		—	—	—	—	—	—	—	—
Total CECONY	$2,281	$2,283		$—		$—	$275	$254	$392	$460	$2		$(2)		$149	$146	$87	$105	$40,353	$39,701	$571	$591
O&R
Electric	$144	$162		$—		$—	$13	$13	$14	$16		$—		$—	$6	$5	$3	$4	$1,928	$1,944	$25	$25
Gas	31	16	—		—		4	4	(1)	(18)	—		—		3	4	(1)	(8)	761	739	12	11
Total O&R	$175	$178		$—		$—	$17	$17	$13	$(2)		$—		$—	$9	$9	$2	$(4)	$2,689	$2,683	$37	$36
Competitive energy businesses	$338	$328	$3		$(1)		$10	$6	$109	$13	$7		$12		$8	$2	$36	$7	$2,494	$1,549	$128	$364
Con Edison Transmission	—	—	—		—		—	—	(1)	—	3		—		1	—	—	—	1,043	2	—	—
Other (a)	—	(1)	(3)		1		—	(1)	2	1	(1)		—		3	5	3	—	691	816	—	—
Total Con Edison	$2,794	$2,788		$—		$—	$302	$276	$515	$472	$11		$10		$170	$162	$128	$108	$47,270	$44,751	$736	$991


(a)	Parent company and consolidation adjustments. Other does not represent a business segment.



	For the Six Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)			Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016		2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$3,665	$3,858	$9		$9		$428	$403	$645	$700	$1		$(1)	$225	$223	$137	$142	$30,632	$30,474	$720	$744
Gas	905	963	3		3		78	70	301	294	(1)		—	52	46	97	98	7,131	6,598	365	289
Steam	343	471	44		43		41	38	87	149	—		—	20	21	35	60	2,590	2,629	51	38
Consolidation adjustments	—	—	(56)		(55)		—	—	—	—	—		—	—	—	—	—	—	—	—	—
Total CECONY	$4,913	$5,292		$—		$—	$547	$511	$1,033	$1,143		$—	$(1)	$297	$290	$269	$300	$40,353	$39,701	$1,136	$1,071
O&R
Electric	$284	$318		$—		$—	$24	$25	$32	$34		$—	$1	$12	$11	$7	$9	$1,928	$1,944	$47	$45
Gas	106	93	—		—		9	9	34	9	—		—	6	6	12	1	761	739	21	17
Total O&R	$390	$411		$—		$—	$33	$34	$66	$43		$—	$1	$18	$17	$19	$10	$2,689	$2,683	$68	$62
Competitive energy businesses	$648	$702	$9		$(4)		$19	$11	$58	$10	$9		$15	$16	$3	$9	$4	$2,494	$1,549	$556	$464
Con Edison Transmission	—	—	—		—		—	—	(1)	—	3		—	1	—	—	—	1,043	2	—	—
Other (a)	(1)	(1)	(9)		4		—	(1)	1	2	—		(1)	7	13	2	—	691	816	—	—
Total Con Edison	$5,950	$6,404		$—		$—	$599	$555	$1,157	$1,198	$12		$14	$339	$323	$299	$314	$47,270	$44,751	$1,760	$1,597


(a)	Parent company and consolidation adjustments. Other does not represent a business segment.

- Definition

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8981-108599

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e9038-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8971-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8380-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8984-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e9031-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e9054-108599

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8538-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8864-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8924-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
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-Section 50
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-URI http://asc.fasb.org/extlink&oid=68060357&loc=d3e8906-108599

+ Details

Derivative Instruments and Hedging Activities

6 Months Ended

Jun. 30, 2016

Derivative [Line Items]

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 consolidated 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 June 30, 2016 and December 31, 2015 were:



(Millions of Dollars)	2016				2015
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	$78	$(50)	$28	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	45	(42)	3		51	(50)	1
Noncurrent	33	(32)	1		57	(54)	3
Noncurrent - assets held for sale (c)	13	(10)	3		15	(15)	—
Total fair value of derivative assets	$169	$(134)	$35		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(129)	$67	$(62)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	(76)	42	(34)		(115)	50	(65)
Noncurrent	(67)	34	(33)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	(24)	10	(14)		(28)	15	(13)
Total fair value of derivative liabilities	$(296)	$153	$(143)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(127)	$19	$(108)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$57	$(47)	$10	(b)	$40	$(32)	$8	(b)
Noncurrent	24	(24)	—		48	(47)	1
Total fair value of derivative assets	$81	$(71)	$10		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(109)	$65	$(44)		$(121)	$71	$(50)
Noncurrent	(59)	29	(30)		(92)	56	(36)
Total fair value of derivative liabilities	$(168)	$94	$(74)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(87)	$23	$(64)	(b)	$(125)	$48	$(77)	(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 June 30, 2016 and December 31, 2015, margin deposits for Con Edison ($16 million and $26 million, respectively) and CECONY ($16 million and $26 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 P).

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 six months ended June 30, 2016 and 2015:



		For the Three Months Ended June 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$10		$(2)		$9		$(1)
Noncurrent	Deferred derivative gains	1		—		—		—
Total deferred gains/(losses)		$11		$(2)		$9		$(1)
Current	Deferred derivative losses	$68		$(11)		$61		$(10)
Current	Recoverable energy costs	(52)		(40)		(47)		(36)
Noncurrent	Deferred derivative losses	68		(2)		62		(1)
Total deferred gains/(losses)		$84		$(53)		$76		$(47)
Net deferred gains/(losses)		$95		$(55)		$85		$(48)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$45	(a)	$(50)	(b)		$—		$—
	Gas purchased for resale	(23)		(26)		—		—
	Non-utility revenue	5	(a)	(27)	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$27		$(103)			$—		$—


(a)	For the three months ended June 30, 2016, Con Edison recorded an unrealized gain in purchase power expense ($97 million gain).


(b)	For the three months ended June 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($1 million gain) and purchased power expense ($17 million loss).



		For the Six Months Ended June 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$7		$1		$5		$2
Noncurrent	Deferred derivative gains	1		—		(1)		—
Total deferred gains/(losses)		$8		$1		$4		$2
Current	Deferred derivative losses	$38		$32		$33		$32
Current	Recoverable energy costs	(125)		(39)		(113)		(38)
Noncurrent	Deferred derivative losses	12		(21)		11		(18)
Total deferred gains/(losses)		$(75)		$(28)		$(69)		$(24)
Net deferred gains/(losses)		$(67)		$(27)		$(65)		$(22)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(70)	(a)	$(28)	(b)		$—		$—
	Gas purchased for resale	(33)		(69)		—		—
	Non-utility revenue	17	(a)	15	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(86)		$(82)			$—		$—


(a)	For the six months ended June 30, 2016, Con Edison recorded unrealized gains and losses in non-utility operating revenue ($1 million loss) and purchase power expense ($35 million gain).


(b)	For the six months ended June 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($3 million loss) and purchased power expense ($5 million loss).

The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at June 30, 2016:



	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison (c)	31,244,951	23,618	39,700,166	3,360,000
CECONY	15,349,625	10,200	38,830,000	3,360,000


(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 14,519,076 MWh for electric energy, 10,779 MW for capacity and 887,007 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 June 30, 2016, Con Edison and CECONY had $191 million and $21 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $79 million with commodity exchange brokers, $67 million with independent system operators, $35 million with investment-grade counterparties and $10 million with non-investment grade/non-rated counterparties. CECONY’s net credit exposure consisted of $17 million with commodity exchange brokers and $4 million with investment-grade counterparties.

The collateral requirements associated with, and settlement of, derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statement of cash flows. Most derivative instrument contracts contain provisions that may require a party to provide collateral on its derivative instruments that are in a net liability position. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the party’s credit ratings.

The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at June 30, 2016:



(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$82		$68
Collateral posted	23		22
Additional collateral (b) (downgrade one level from current ratings)	4		3
Additional collateral (b) (downgrade to below investment grade from current ratings)	99	(c)	76	(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 $4 million at June 30, 2016. 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 June 30, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $20 million.

CECONY

Derivative [Line Items]

Derivative Instruments and Hedging Activities

The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at June 30, 2016 and December 31, 2015 were:



(Millions of Dollars)	2016				2015
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	$78	$(50)	$28	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	45	(42)	3		51	(50)	1
Noncurrent	33	(32)	1		57	(54)	3
Noncurrent - assets held for sale (c)	13	(10)	3		15	(15)	—
Total fair value of derivative assets	$169	$(134)	$35		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(129)	$67	$(62)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	(76)	42	(34)		(115)	50	(65)
Noncurrent	(67)	34	(33)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	(24)	10	(14)		(28)	15	(13)
Total fair value of derivative liabilities	$(296)	$153	$(143)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(127)	$19	$(108)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$57	$(47)	$10	(b)	$40	$(32)	$8	(b)
Noncurrent	24	(24)	—		48	(47)	1
Total fair value of derivative assets	$81	$(71)	$10		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(109)	$65	$(44)		$(121)	$71	$(50)
Noncurrent	(59)	29	(30)		(92)	56	(36)
Total fair value of derivative liabilities	$(168)	$94	$(74)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(87)	$23	$(64)	(b)	$(125)	$48	$(77)	(b)

(a)

(b)


(c)	Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet (see Note P).



		For the Three Months Ended June 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$10		$(2)		$9		$(1)
Noncurrent	Deferred derivative gains	1		—		—		—
Total deferred gains/(losses)		$11		$(2)		$9		$(1)
Current	Deferred derivative losses	$68		$(11)		$61		$(10)
Current	Recoverable energy costs	(52)		(40)		(47)		(36)
Noncurrent	Deferred derivative losses	68		(2)		62		(1)
Total deferred gains/(losses)		$84		$(53)		$76		$(47)
Net deferred gains/(losses)		$95		$(55)		$85		$(48)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$45	(a)	$(50)	(b)		$—		$—
	Gas purchased for resale	(23)		(26)		—		—
	Non-utility revenue	5	(a)	(27)	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$27		$(103)			$—		$—


(a)	For the three months ended June 30, 2016, Con Edison recorded an unrealized gain in purchase power expense ($97 million gain).


(b)	For the three months ended June 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($1 million gain) and purchased power expense ($17 million loss).



		For the Six Months Ended June 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$7		$1		$5		$2
Noncurrent	Deferred derivative gains	1		—		(1)		—
Total deferred gains/(losses)		$8		$1		$4		$2
Current	Deferred derivative losses	$38		$32		$33		$32
Current	Recoverable energy costs	(125)		(39)		(113)		(38)
Noncurrent	Deferred derivative losses	12		(21)		11		(18)
Total deferred gains/(losses)		$(75)		$(28)		$(69)		$(24)
Net deferred gains/(losses)		$(67)		$(27)		$(65)		$(22)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(70)	(a)	$(28)	(b)		$—		$—
	Gas purchased for resale	(33)		(69)		—		—
	Non-utility revenue	17	(a)	15	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(86)		$(82)			$—		$—


(a)	For the six months ended June 30, 2016, Con Edison recorded unrealized gains and losses in non-utility operating revenue ($1 million loss) and purchase power expense ($35 million gain).


(b)	For the six months ended June 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($3 million loss) and purchased power expense ($5 million loss).

The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at June 30, 2016:



	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison (c)	31,244,951	23,618	39,700,166	3,360,000
CECONY	15,349,625	10,200	38,830,000	3,360,000


(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 14,519,076 MWh for electric energy, 10,779 MW for capacity and 887,007 Dt for natural gas derivative transactions that are held for sale.



(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$82		$68
Collateral posted	23		22
Additional collateral (b) (downgrade one level from current ratings)	4		3
Additional collateral (b) (downgrade to below investment grade from current ratings)	99	(c)	76	(c)

(a)

(b)


(c)	Derivative instruments that are net assets have been excluded from the table. At June 30, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $20 million.

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
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-Name Accounting Standards Codification
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+ Details

Fair Value Measurements

6 Months Ended

Jun. 30, 2016

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

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 June 30, 2016 and December 31, 2015 are summarized below.



	2016						2015
(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)	$3	$28	$9		$5	$45	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	47	4		(45)	6	—	63	1		(63)	1
Other (a)(b)(d)	201	117	—		—	318	185	112	—		—	297
Total assets	$204	$192	$13		$(40)	$369	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$4	$118	$3		$(30)	$95	$16	$153	$1		$(65)	$105
Commodity held for sale (f)	—	88	5		(45)	48	1	133	7		(63)	78
Total liabilities	$4	$206	$8		$(75)	$143	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$2	$14	$2		$8	$26	$1	$9	$8		$17	$35
Other (a)(b)(d)	193	104	—		—	297	171	105	—		—	276
Total assets	$195	$118	$2		$8	$323	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$3	$102		$—	$(31)	$74	$14	$129		$—	$(57)	$86


(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 six months ended June 30, 2016 and for the year ended December 31, 2015.

(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 June 30, 2016 and December 31, 2015, 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 P).

The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives. 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 June 30, 2016	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$2	Discounted Cash Flow	Forward energy prices (a)	$19.50-$86.50 per MWh
		Discounted Cash Flow	Forward capacity prices (a)	$1.65-$12.25 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	3	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
			Discount/premium to adjust auction prices for historical monthly realized settlements (b)	53.3%-144.9%
			Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.86-$2.53 per MWh
Total Con Edison—Commodity	$5
CECONY—Commodity
Transmission Congestion Contracts	$2	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
			Discount/premium to adjust auction prices for historical monthly realized settlements (b)	53.3%-144.9%


(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 June 30, 2016 and 2015 and classified as Level 3 in the fair value hierarchy:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of April 1,	$(4)	$11	$2	$12
Included in earnings	5	(3)	—	(2)
Included in regulatory assets and liabilities	1	—	(1)	—
Purchases	1	5	1	2
Settlements	2	—	—	(1)
Ending balance as of June 30,	$5	$13	$2	$11



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of January 1,	$6	$20	$8	$13
Included in earnings	(2)	(15)	(1)	(5)
Included in regulatory assets and liabilities	(2)	1	(5)	1
Purchases	1	8	1	4
Settlements	2	(1)	(1)	(2)
Ending balance as of June 30,	$5	$13	$2	$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 ($5 million gain and $1 million loss) on the consolidated income statement for the three months ended June 30, 2016 and 2015, 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 ($2 million loss and $10 million loss) on the consolidated income statement for the six months ended June 30, 2016, and 2015, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at June 30, 2016 and 2015 is included in non-utility revenues (immaterial for both periods) and purchased power costs ($7 million gain and $1 million gain) on the consolidated income statement for the three months ended June 30, 2016 and 2015, respectively. For the six months ended June 30, 2016, and 2015, 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 ($3 million gain and $4 million loss) on the consolidated income statement, respectively.

CECONY

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value Measurements

•

Assets and liabilities measured at fair value on a recurring basis as of June 30, 2016 and December 31, 2015 are summarized below.



	2016						2015
(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)	$3	$28	$9		$5	$45	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	47	4		(45)	6	—	63	1		(63)	1
Other (a)(b)(d)	201	117	—		—	318	185	112	—		—	297
Total assets	$204	$192	$13		$(40)	$369	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$4	$118	$3		$(30)	$95	$16	$153	$1		$(65)	$105
Commodity held for sale (f)	—	88	5		(45)	48	1	133	7		(63)	78
Total liabilities	$4	$206	$8		$(75)	$143	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$2	$14	$2		$8	$26	$1	$9	$8		$17	$35
Other (a)(b)(d)	193	104	—		—	297	171	105	—		—	276
Total assets	$195	$118	$2		$8	$323	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$3	$102		$—	$(31)	$74	$14	$129		$—	$(57)	$86


(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 six months ended June 30, 2016 and for the year ended December 31, 2015.

(b)

(c)


(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 P).



	Fair Value of Level 3 at June 30, 2016	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$2	Discounted Cash Flow	Forward energy prices (a)	$19.50-$86.50 per MWh
		Discounted Cash Flow	Forward capacity prices (a)	$1.65-$12.25 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	3	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
			Discount/premium to adjust auction prices for historical monthly realized settlements (b)	53.3%-144.9%
			Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.86-$2.53 per MWh
Total Con Edison—Commodity	$5
CECONY—Commodity
Transmission Congestion Contracts	$2	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
			Discount/premium to adjust auction prices for historical monthly realized settlements (b)	53.3%-144.9%


(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.



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of April 1,	$(4)	$11	$2	$12
Included in earnings	5	(3)	—	(2)
Included in regulatory assets and liabilities	1	—	(1)	—
Purchases	1	5	1	2
Settlements	2	—	—	(1)
Ending balance as of June 30,	$5	$13	$2	$11



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of January 1,	$6	$20	$8	$13
Included in earnings	(2)	(15)	(1)	(5)
Included in regulatory assets and liabilities	(2)	1	(5)	1
Purchases	1	8	1	4
Settlements	2	(1)	(1)	(2)
Ending balance as of June 30,	$5	$13	$2	$11

Variable Interest Entities

6 Months Ended

Jun. 30, 2016

Schedule of Equity Method Investments [Line Items]

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 had a variable interest in a non-consolidated variable interest entity (VIE), Astoria Energy, LLC (Astoria Energy), with which CECONY entered into a long-term electricity purchase agreement that expired in April 2016. CECONY has ongoing long-term electricity purchase agreements with the following two potential VIEs: Cogen Technologies Linden Venture, LP, and Brooklyn Navy Yard Cogeneration Partners, LP. In 2015, requests were made of these two 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 for these contracts constitute CECONY’s maximum exposure to loss with respect to the potential VIEs.

The following table summarizes the VIEs in which Con Edison Development has entered into as of June 30, 2016:



Project Name (a)	Generating Capacity (b) (MW 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	$184
Panoche Valley	120	20	2015	California	204
Mesquite Solar 1	83	20	2013	Arizona	105
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	68
Broken Bow II	38	25	2014	Nebraska	54
Texas Solar 4	32	25	2014	Texas	15
Pilesgrove (e)	9	n/a (d)	2010	New Jersey	18

(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 an $8 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 3-4 year Solar Renewable Energy Credit hedges in place.

(e) Carrying value and maximum exposure reduced by an $8 million impairment charge in June 2016 (included in Investment and other income on Con Edison's consolidated income statement).

CECONY

Schedule of Equity Method Investments [Line Items]

Variable Interest Entities

The following table summarizes the VIEs in which Con Edison Development has entered into as of June 30, 2016:



Project Name (a)	Generating Capacity (b) (MW 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	$184
Panoche Valley	120	20	2015	California	204
Mesquite Solar 1	83	20	2013	Arizona	105
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	68
Broken Bow II	38	25	2014	Nebraska	54
Texas Solar 4	32	25	2014	Texas	15
Pilesgrove (e)	9	n/a (d)	2010	New Jersey	18

(b) Represents Con Edison Development’s ownership interest in the project.

(d) Pilesgrove has 3-4 year Solar Renewable Energy Credit hedges in place.

(e) Carrying value and maximum exposure reduced by an $8 million impairment charge in June 2016 (included in Investment and other income on Con Edison's consolidated income statement).

Related Party Transactions	6 Months Ended
Related Party Transactions	Jun. 30, 2016
Related Party Transactions	Related Party Transactions The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric has a 45.7 percent equity interest (see Note Q). The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the three and six months ended June 30, 2016, the amounts billed by CECONY to NY Transco were immaterial. CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC (Stagecoach), a joint venture formed by a subsidiary of CET Gas and a subsidiary of Crestwood Equity Partners LP (Crestwood) (see Note Q). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. Since the formation of the joint venture in June 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $3 million. CECONY has a financial electric capacity contract with Con Edison Energy for the period May 2016 through April 2017. For the three and six months ended June 30, 2016, Con Edison Energy's realized losses under this contract were immaterial to earnings.
CECONY
Related Party Transactions	Related Party Transactions The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric has a 45.7 percent equity interest (see Note Q). The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the three and six months ended June 30, 2016, the amounts billed by CECONY to NY Transco were immaterial. CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC (Stagecoach), a joint venture formed by a subsidiary of CET Gas and a subsidiary of Crestwood Equity Partners LP (Crestwood) (see Note Q). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. Since the formation of the joint venture in June 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $3 million. CECONY has a financial electric capacity contract with Con Edison Energy for the period May 2016 through April 2017. For the three and six months ended June 30, 2016, Con Edison Energy's realized losses under this contract were immaterial to earnings.

New Financial Accounting Standards	6 Months Ended
New Financial Accounting Standards	Jun. 30, 2016
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 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. Additionally, in March and April 2016, respectively, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations (Reporting Revenue Gross Versus Net)” to clarify how to apply the implementation guidance for principal versus agent considerations and ASU No. 2016-10, “Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing” to clarify the guidance pertaining to identifying performance obligations and licensing implementation guidance. Furthermore in May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” to clarify assessing collectibility, presentation of sales taxes, non-cash consideration, contract modification at transition, and completed contracts at transition. The new standard is effective for reporting periods beginning after December 15, 2017. 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 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity. In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity. In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning 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 March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning 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 March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” This amendment requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments in this Update are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning 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 May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of the 2014-09 and 2014-16. The Companies are in the process of evaluating the potential impact of the amendments on the Companies’ financial position, results of operations and liquidity. In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted where entities may adopt earlier as of the fiscal years beginning after December 15, 2018 including interim periods within those fiscal years. 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 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. Additionally, in March and April 2016, respectively, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations (Reporting Revenue Gross Versus Net)” to clarify how to apply the implementation guidance for principal versus agent considerations and ASU No. 2016-10, “Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing” to clarify the guidance pertaining to identifying performance obligations and licensing implementation guidance. Furthermore in May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” to clarify assessing collectibility, presentation of sales taxes, non-cash consideration, contract modification at transition, and completed contracts at transition. The new standard is effective for reporting periods beginning after December 15, 2017. 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 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity. In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity. In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning 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 March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning 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 March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” This amendment requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments in this Update are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning 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 May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of the 2014-09 and 2014-16. The Companies are in the process of evaluating the potential impact of the amendments on the Companies’ financial position, results of operations and liquidity. In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted where entities may adopt earlier as of the fiscal years beginning after December 15, 2018 including interim periods within those fiscal years. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

- Definition

The entire disclosure of changes in accounting principles, including adoption of new accounting pronouncements, that describes the new methods, amount and effects on financial statement line items.

+ References

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+ Details

Assets Held For Sale

6 Months Ended

Jun. 30, 2016

Discontinued Operations and Disposal Groups [Abstract]

Assets Held For Sale

In July 2016, Con Edison Solutions entered into an agreement to sell the assets of its retail electric supply business (including retail contracts, related derivative instruments, information systems, and accounts receivable) to a subsidiary of Exelon Corporation. The company estimates that it will receive proceeds from the sale of approximately $200 million, subject to certain adjustments. The earnings impact of the sale will be determinable at closing when the mark-to-market effects of the derivative instruments being sold are known. The transaction is expected to close by the end of the year.

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 (Corning) for $16 million, including estimated working capital adjustments. The closing of the sale, which the company expects to occur in 2016, is subject to certain regulatory approvals by the FERC and Pennsylvania Public Utility Commission (PAPUC). In March 2016, FERC approved a proposed electric supply agreement between O&R and Pike. In June 2016, FERC approved a proposed gas supply and gas transportation agreement between O&R and Pike. In June 2016, the administrative law judge presiding over the PAPUC proceeding approved a joint settlement petition submitted by Pike, O&R, Corning and other parties, which is subject to PAPUC approval. In 2015, the company classified the related electric and gas assets and liabilities as held for sale and ceased recording depreciation expense on these assets. At September 30, 2015, 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 reflected in the amount included in assets held for sale on the company's consolidated balance sheet at June 30, 2016.

At June 30, 2016, 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		$—	$4		$4
Accounts receivable less allowance for uncollectible accounts of $2	70		—		70
Accrued unbilled revenue	79		1		80
Other assets	4		1		5
Total current assets	153		6		159
Utility plant, less accumulated depreciation of $6	—		14		14
Non-utility property, less accumulated depreciation of $13	3		—		3
Non-utility property construction work in progress	1		—		1
Regulatory assets	—		3		3
Other assets	3		—		3
Total assets held for sale	$160		$23		$183

Fair value of derivative liabilities	$34			$—	$34
Accounts payable	5		—		5
Other	3		1		4
Total current liabilities	42		1		43
Fair value of derivative liabilities	14		—		14
Long-term debt	—		3		3
Total liabilities held for sale	$56		$4		$60

- Definition

The entire disclosure related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

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+ Details

Acquisitions, Investments and Dispositions	6 Months Ended
Acquisitions, Investments and Dispositions	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Acquisitions, Investments and Dispositions	Acquisitions, Investments and Dispositions Texas Solar 7 In January 2016, Con Edison Development acquired a company that is the owner of a 106 MW (AC) solar electric production project in Texas (Texas Solar 7) for $227 million; $218 million was recorded as non-utility construction work in progress and the remaining $9 million was recorded as other receivables. The total cost of this project is expected to be approximately $375 million. The project has been financed, in part, by debt secured by the project (see Note C). Electricity generated by this project is to be purchased by the City of San Antonio pursuant to a long-term power purchase agreement. The project is targeted to be fully in-service during 2016. Mountain Valley Pipeline In January 2016, CET Gas acquired a 12.5 percent equity interest in Mountain Valley Pipeline, LLC (MVP), a company developing a proposed gas transmission project in West Virginia and Virginia. The company's initial contribution to MVP was $18 million. The estimated total project cost is $3,000 million to $3,500 million. Subject to FERC approval, MVP is targeting to be fully in-service during 2018. Con Edison is accounting for its equity interest in MVP as an equity method investment. Stagecoach Gas Services In April 2016, a CET Gas subsidiary agreed with a subsidiary of Crestwood to form a joint venture to own, operate and further develop existing natural gas pipeline and storage businesses located in northern Pennsylvania and southern New York. The transaction was substantially completed during June 2016. Crestwood contributed businesses to a new entity, Stagecoach, and the CET Gas subsidiary purchased a 50 percent equity interest in Stagecoach for $945 million (subject to closing adjustments). Con Edison is accounting for its equity interest in Stagecoach as an equity method investment. NY Transco In January 2016, CECONY entered into an agreement to transfer certain electric transmission projects to NY Transco, a company in which CET Electric has a 45.7 percent equity interest. In April 2016, the NYSPSC authorized CECONY, subject to certain conditions, to transfer the projects to NY Transco. In May 2016, CECONY transferred the projects to NY Transco for a purchase price of $122 million and an $8 million payment for easement rights on certain associated property. Also, through June 2016, CET Electric contributed $48 million to NY Transco in connection with the purchase of the projects. Con Edison is accounting for its equity interest in NY Transco as an equity method investment. Assets Held For Sale In October 2015, O&R entered into an agreement to sell Pike to Corning. In July 2016, Con Edison Solutions entered into an agreement to sell the assets of its retail electric supply business to a subsidiary of Exelon Corporation. See Note P.

Summary of Significant Accounting Policies (Policies)	6 Months Ended
Summary of Significant Accounting Policies (Policies)	Jun. 30, 2016
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 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. Additionally, in March and April 2016, respectively, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations (Reporting Revenue Gross Versus Net)” to clarify how to apply the implementation guidance for principal versus agent considerations and ASU No. 2016-10, “Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing” to clarify the guidance pertaining to identifying performance obligations and licensing implementation guidance. Furthermore in May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” to clarify assessing collectibility, presentation of sales taxes, non-cash consideration, contract modification at transition, and completed contracts at transition. The new standard is effective for reporting periods beginning after December 15, 2017. 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 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity. In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity. In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning 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 March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning 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 March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” This amendment requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments in this Update are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning 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 May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of the 2014-09 and 2014-16. The Companies are in the process of evaluating the potential impact of the amendments on the Companies’ financial position, results of operations and liquidity. In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted where entities may adopt earlier as of the fiscal years beginning after December 15, 2018 including interim periods within those fiscal years. 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 Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Earnings Per Common Share

For the three and six months ended June 30, 2016 and 2015, basic and diluted earnings per share (EPS) for Con Edison are calculated as follows:



	For the Three Months Ended June 30,		For the Six Months Ended June 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2016	2015
Net income	$232	$219	$542	$589
Weighted average common shares outstanding – basic	299.1	292.9	296.7	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.3	1.1	1.3	1.0
Adjusted weighted average common shares outstanding – diluted	300.4	294.0	298.0	293.9
Net income per common share – basic	$0.78	$0.75	$1.83	$2.01
Net income per common share – diluted	$0.77	$0.74	$1.82	$2.01

Changes in Accumulated Other Comprehensive Income/(Loss) by Component

For the three and six months ended June 30, 2016 and 2015, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(40)	$(9)	$(11)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015 (a)(b)	1	1	1	1
Current period OCI, net of taxes	1	1	1	1
Ending balance, accumulated OCI, net of taxes	$(33)	$(39)	$(8)	$(10)



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(45)	$(9)	$(11)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively	(1)	3	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2016 and 2015 (a)(b)	2	3	1	1
Current period OCI, net of taxes	1	6	1	1
Ending balance, accumulated OCI, net of taxes	$(33)	$(39)	$(8)	$(10)


(a)	Tax reclassified from accumulated OCI is reported in the income tax expense line item of the consolidated income statement.


(b)	For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets 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)

6 Months Ended

Jun. 30, 2016

Regulated Operations [Abstract]

Regulatory Assets and Liabilities

Regulatory assets and liabilities at June 30, 2016 and December 31, 2015 were comprised of the following items:



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$3,516	$3,876	$3,361	$3,697
Future income tax	2,379	2,350	2,262	2,232
Environmental remediation costs	837	904	732	800
Revenue taxes	295	253	281	240
Deferred storm costs	122	185	57	110
Unamortized loss on reacquired debt	47	50	44	48
O&R property tax reconciliation	42	46	—	—
Deferred derivative losses	38	50	35	46
Pension and other postretirement benefits deferrals	35	45	6	16
Net electric deferrals	34	44	34	44
Surcharge for New York State assessment	32	44	29	40
Preferred stock redemption	26	26	26	26
O&R transition bond charges	18	21	—	—
Workers’ compensation	16	11	16	11
Recoverable energy costs	—	16	—	15
Other	243	175	226	157
Regulatory assets – noncurrent	7,680	8,096	7,109	7,482
Deferred derivative losses	75	113	70	103
Recoverable energy costs	9	19	7	18
Regulatory assets – current	84	132	77	121
Total Regulatory Assets	$7,764	$8,228	$7,186	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$708	$676	$599	$570
Property tax reconciliation	230	303	230	303
Pension and other postretirement benefit deferrals	125	76	96	46
Net unbilled revenue deferrals	117	109	117	109
Prudence proceeding	97	99	97	99
Unrecognized other postretirement costs	93	28	93	28
Base rate change deferrals	77	128	77	128
New York State income tax rate change	69	75	66	72
Variable-rate tax-exempt debt – cost rate reconciliation	64	70	56	60
Carrying charges on repair allowance and bonus depreciation	51	49	50	48
Earnings sharing - electric, gas and steam	34	80	30	80
Net utility plant reconciliations	28	32	28	31
Property tax refunds	22	44	22	44
World Trade Center settlement proceeds	10	21	10	21
Other	207	187	172	150
Regulatory liabilities – noncurrent	1,932	1,977	1,743	1,789
Revenue decoupling mechanism	79	45	78	45
Refundable energy costs	30	64	9	33
Deferred derivative gains	13	6	11	6
Regulatory liabilities – current	122	115	98	84
Total Regulatory Liabilities	$2,054	$2,092	$1,841	$1,873

Pension Benefits (Tables)

6 Months Ended

Jun. 30, 2016

Pension Benefits

Total Periodic Benefit Costs

The components of the Companies’ total periodic benefit costs for the three and six months ended June 30, 2016 and 2015 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$69	$74	$65	$70
Interest cost on projected benefit obligation	149	144	140	135
Expected return on plan assets	(237)	(222)	(225)	(210)
Recognition of net actuarial loss	149	194	141	183
Recognition of prior service costs	1	1	—	—
NET PERIODIC BENEFIT COST	$131	$191	$121	$178
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$131	$192	$121	$179
Cost capitalized	(53)	(76)	(50)	(72)
Reconciliation to rate level	13	(17)	14	(18)
Cost charged to operating expenses	$91	$99	$85	$89



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$138	$149	$129	$139
Interest cost on projected benefit obligation	298	287	280	269
Expected return on plan assets	(474)	(443)	(449)	(420)
Recognition of net actuarial loss	298	388	282	367
Recognition of prior service costs	2	2	1	1
NET PERIODIC BENEFIT COST	$262	$383	$243	$356
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$262	$384	$243	$357
Cost capitalized	(106)	(144)	(99)	(137)
Reconciliation to rate level	26	(42)	26	(42)
Cost charged to operating expenses	$182	$198	$170	$178

Other Postretirement Benefits (Tables)

6 Months Ended

Jun. 30, 2016

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 six months ended June 30, 2016 and 2015 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost	$4	$5	$3	$4
Interest cost on accumulated other postretirement benefit obligation	12	13	10	11
Expected return on plan assets	(19)	(20)	(17)	(17)
Recognition of net actuarial loss	1	8	1	7
Recognition of prior service cost	(5)	(5)	(3)	(4)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(7)	$1	$(6)	$1
Cost capitalized	2	(1)	2	(1)
Reconciliation to rate level	7	4	6	2
Cost charged to operating expenses	$2	$4	$2	$2



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost	$9	$10	$7	$7
Interest cost on accumulated other postretirement benefit obligation	24	25	20	22
Expected return on plan assets	(38)	(39)	(34)	(34)
Recognition of net actuarial loss	2	16	1	14
Recognition of prior service cost	(10)	(10)	(7)	(7)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(13)	$2	$(13)	$2
Cost capitalized	3	(1)	3	(1)
Reconciliation to rate level	14	8	14	3
Cost charged to operating expenses	$4	$9	$4	$4

Environmental Matters (Tables)

6 Months Ended

Jun. 30, 2016

Environmental Remediation Obligations [Abstract]

Accrued Liabilities and Regulatory Assets

The accrued liabilities and regulatory assets related to Superfund Sites at June 30, 2016 and December 31, 2015 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$670	$679	$576	$579
Other Superfund Sites	88	86	88	86
Total	$758	$765	$664	$665
Regulatory assets	$837	$904	$732	$800

Environmental Remediation Costs

Environmental remediation costs incurred related to Superfund Sites for the three and six months ended June 30, 2016 and 2015 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$9	$8	$3	$7



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$12	$15	$5	$12

Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings



	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$91	$86	$86	$81
Regulatory assets – workers’ compensation	$16	$11	$16	$11

Other Material Contingencies (Tables)

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Total Guarantees

A summary, by type and term, of Con Edison’s total guarantees at June 30, 2016 is as follows:



Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$619	$583		$—	$1,202
Energy transactions	672	41	91		804
Renewable electric production projects	443	—	20		463
Other	75	—	—		75
Total	$1,809	$624	$111		$2,544

Financial Information by Business Segment (Tables)

6 Months Ended

Jun. 30, 2016

Segment Reporting [Abstract]

Financial Data for Business Segments

The financial data for the business segments are as follows:



	For the Three Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)				Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$1,892	$1,879	$4		$5		$215	$201	$371	$422	$2		$(1)		$113	$113	$88	$99	$30,632	$30,474	$338	$409
Gas	304	308	1		1		39	35	48	54	—		(1)		26	23	9	12	7,131	6,598	205	161
Steam	85	96	21		21		21	18	(27)	(16)	—		—		10	10	(10)	(6)	2,590	2,629	28	21
Consolidation adjustments	—	—	(26)		(27)		—	—	—	—	—		—		—	—	—	—	—	—	—	—
Total CECONY	$2,281	$2,283		$—		$—	$275	$254	$392	$460	$2		$(2)		$149	$146	$87	$105	$40,353	$39,701	$571	$591
O&R
Electric	$144	$162		$—		$—	$13	$13	$14	$16		$—		$—	$6	$5	$3	$4	$1,928	$1,944	$25	$25
Gas	31	16	—		—		4	4	(1)	(18)	—		—		3	4	(1)	(8)	761	739	12	11
Total O&R	$175	$178		$—		$—	$17	$17	$13	$(2)		$—		$—	$9	$9	$2	$(4)	$2,689	$2,683	$37	$36
Competitive energy businesses	$338	$328	$3		$(1)		$10	$6	$109	$13	$7		$12		$8	$2	$36	$7	$2,494	$1,549	$128	$364
Con Edison Transmission	—	—	—		—		—	—	(1)	—	3		—		1	—	—	—	1,043	2	—	—
Other (a)	—	(1)	(3)		1		—	(1)	2	1	(1)		—		3	5	3	—	691	816	—	—
Total Con Edison	$2,794	$2,788		$—		$—	$302	$276	$515	$472	$11		$10		$170	$162	$128	$108	$47,270	$44,751	$736	$991


(a)	Parent company and consolidation adjustments. Other does not represent a business segment.



	For the Six Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)			Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016		2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$3,665	$3,858	$9		$9		$428	$403	$645	$700	$1		$(1)	$225	$223	$137	$142	$30,632	$30,474	$720	$744
Gas	905	963	3		3		78	70	301	294	(1)		—	52	46	97	98	7,131	6,598	365	289
Steam	343	471	44		43		41	38	87	149	—		—	20	21	35	60	2,590	2,629	51	38
Consolidation adjustments	—	—	(56)		(55)		—	—	—	—	—		—	—	—	—	—	—	—	—	—
Total CECONY	$4,913	$5,292		$—		$—	$547	$511	$1,033	$1,143		$—	$(1)	$297	$290	$269	$300	$40,353	$39,701	$1,136	$1,071
O&R
Electric	$284	$318		$—		$—	$24	$25	$32	$34		$—	$1	$12	$11	$7	$9	$1,928	$1,944	$47	$45
Gas	106	93	—		—		9	9	34	9	—		—	6	6	12	1	761	739	21	17
Total O&R	$390	$411		$—		$—	$33	$34	$66	$43		$—	$1	$18	$17	$19	$10	$2,689	$2,683	$68	$62
Competitive energy businesses	$648	$702	$9		$(4)		$19	$11	$58	$10	$9		$15	$16	$3	$9	$4	$2,494	$1,549	$556	$464
Con Edison Transmission	—	—	—		—		—	—	(1)	—	3		—	1	—	—	—	1,043	2	—	—
Other (a)	(1)	(1)	(9)		4		—	(1)	1	2	—		(1)	7	13	2	—	691	816	—	—
Total Con Edison	$5,950	$6,404		$—		$—	$599	$555	$1,157	$1,198	$12		$14	$339	$323	$299	$314	$47,270	$44,751	$1,760	$1,597


(a)	Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and Hedging Activities (Tables)

6 Months Ended

Jun. 30, 2016

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 June 30, 2016 and December 31, 2015 were:



(Millions of Dollars)	2016				2015
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	$78	$(50)	$28	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	45	(42)	3		51	(50)	1
Noncurrent	33	(32)	1		57	(54)	3
Noncurrent - assets held for sale (c)	13	(10)	3		15	(15)	—
Total fair value of derivative assets	$169	$(134)	$35		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(129)	$67	$(62)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	(76)	42	(34)		(115)	50	(65)
Noncurrent	(67)	34	(33)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	(24)	10	(14)		(28)	15	(13)
Total fair value of derivative liabilities	$(296)	$153	$(143)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(127)	$19	$(108)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$57	$(47)	$10	(b)	$40	$(32)	$8	(b)
Noncurrent	24	(24)	—		48	(47)	1
Total fair value of derivative assets	$81	$(71)	$10		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(109)	$65	$(44)		$(121)	$71	$(50)
Noncurrent	(59)	29	(30)		(92)	56	(36)
Total fair value of derivative liabilities	$(168)	$94	$(74)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(87)	$23	$(64)	(b)	$(125)	$48	$(77)	(b)

(a)

(b)


(c)	Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet (see Note P).

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 June 30, 2016 and December 31, 2015 were:



(Millions of Dollars)	2016				2015
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	$78	$(50)	$28	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	45	(42)	3		51	(50)	1
Noncurrent	33	(32)	1		57	(54)	3
Noncurrent - assets held for sale (c)	13	(10)	3		15	(15)	—
Total fair value of derivative assets	$169	$(134)	$35		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(129)	$67	$(62)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	(76)	42	(34)		(115)	50	(65)
Noncurrent	(67)	34	(33)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	(24)	10	(14)		(28)	15	(13)
Total fair value of derivative liabilities	$(296)	$153	$(143)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(127)	$19	$(108)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$57	$(47)	$10	(b)	$40	$(32)	$8	(b)
Noncurrent	24	(24)	—		48	(47)	1
Total fair value of derivative assets	$81	$(71)	$10		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(109)	$65	$(44)		$(121)	$71	$(50)
Noncurrent	(59)	29	(30)		(92)	56	(36)
Total fair value of derivative liabilities	$(168)	$94	$(74)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(87)	$23	$(64)	(b)	$(125)	$48	$(77)	(b)

(a)

(b)


(c)	Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet (see Note P).

Realized and Unrealized Gains or Losses on Commodity Derivatives



		For the Three Months Ended June 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$10		$(2)		$9		$(1)
Noncurrent	Deferred derivative gains	1		—		—		—
Total deferred gains/(losses)		$11		$(2)		$9		$(1)
Current	Deferred derivative losses	$68		$(11)		$61		$(10)
Current	Recoverable energy costs	(52)		(40)		(47)		(36)
Noncurrent	Deferred derivative losses	68		(2)		62		(1)
Total deferred gains/(losses)		$84		$(53)		$76		$(47)
Net deferred gains/(losses)		$95		$(55)		$85		$(48)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$45	(a)	$(50)	(b)		$—		$—
	Gas purchased for resale	(23)		(26)		—		—
	Non-utility revenue	5	(a)	(27)	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$27		$(103)			$—		$—


(a)	For the three months ended June 30, 2016, Con Edison recorded an unrealized gain in purchase power expense ($97 million gain).


(b)	For the three months ended June 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($1 million gain) and purchased power expense ($17 million loss).



		For the Six Months Ended June 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$7		$1		$5		$2
Noncurrent	Deferred derivative gains	1		—		(1)		—
Total deferred gains/(losses)		$8		$1		$4		$2
Current	Deferred derivative losses	$38		$32		$33		$32
Current	Recoverable energy costs	(125)		(39)		(113)		(38)
Noncurrent	Deferred derivative losses	12		(21)		11		(18)
Total deferred gains/(losses)		$(75)		$(28)		$(69)		$(24)
Net deferred gains/(losses)		$(67)		$(27)		$(65)		$(22)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(70)	(a)	$(28)	(b)		$—		$—
	Gas purchased for resale	(33)		(69)		—		—
	Non-utility revenue	17	(a)	15	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(86)		$(82)			$—		$—


(a)	For the six months ended June 30, 2016, Con Edison recorded unrealized gains and losses in non-utility operating revenue ($1 million loss) and purchase power expense ($35 million gain).


(b)	For the six months ended June 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($3 million loss) and purchased power expense ($5 million loss).

Hedged Volume of Derivative Transactions

The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at June 30, 2016:



	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison (c)	31,244,951	23,618	39,700,166	3,360,000
CECONY	15,349,625	10,200	38,830,000	3,360,000


(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 14,519,076 MWh for electric energy, 10,779 MW for capacity and 887,007 Dt for natural gas derivative transactions that are held for sale.

Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features



(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$82		$68
Collateral posted	23		22
Additional collateral (b) (downgrade one level from current ratings)	4		3
Additional collateral (b) (downgrade to below investment grade from current ratings)	99	(c)	76	(c)

(a)

(b)


(c)	Derivative instruments that are net assets have been excluded from the table. At June 30, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $20 million.

- Definition

Tabular disclosure of credit derivatives which includes information by sellers of credit derivatives, about each credit derivative, or each group of similar credit derivatives, including (a) the nature of the credit derivative - its term, how it arose, the events or circumstances that would require the seller to perform under the credit derivative, and the current status of the payment/performance risk of the credit derivative; (b) the maximum potential amount of future payments (undiscounted) the seller could be required to make under the credit derivative; (c) the current fair value of the credit derivative; and (d) the nature of any recourse provisions under the credit derivative, and any assets held either as collateral or by third parties. A credit derivative is a derivative instrument (1) in which one or more of its underlyings are related to the credit risk of a specified entity (or a group of entities) or an index based on the credit risk of a group of entities and (2) that exposes the seller to potential loss from credit-risk-related events specified in the contract. Examples of credit derivatives within the scope of this paragraph include, but are not limited to, credit default swaps, credit spread options, and credit index products; also includes a hybrid instrument that has an embedded credit derivative (for example, but not limited to, a credit-linked note).

+ References + Details

- Definition

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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+ Details

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2016

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 June 30, 2016 and December 31, 2015 are summarized below.



	2016						2015
(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)	$3	$28	$9		$5	$45	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	47	4		(45)	6	—	63	1		(63)	1
Other (a)(b)(d)	201	117	—		—	318	185	112	—		—	297
Total assets	$204	$192	$13		$(40)	$369	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$4	$118	$3		$(30)	$95	$16	$153	$1		$(65)	$105
Commodity held for sale (f)	—	88	5		(45)	48	1	133	7		(63)	78
Total liabilities	$4	$206	$8		$(75)	$143	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$2	$14	$2		$8	$26	$1	$9	$8		$17	$35
Other (a)(b)(d)	193	104	—		—	297	171	105	—		—	276
Total assets	$195	$118	$2		$8	$323	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$3	$102		$—	$(31)	$74	$14	$129		$—	$(57)	$86


(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 six months ended June 30, 2016 and for the year ended December 31, 2015.

(b)

(c)


(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 P).

Schedule of Commodity Derivatives

The risk management group reports to the Companies’ Vice President and Treasurer.



	Fair Value of Level 3 at June 30, 2016	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$2	Discounted Cash Flow	Forward energy prices (a)	$19.50-$86.50 per MWh
		Discounted Cash Flow	Forward capacity prices (a)	$1.65-$12.25 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	3	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
			Discount/premium to adjust auction prices for historical monthly realized settlements (b)	53.3%-144.9%
			Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.86-$2.53 per MWh
Total Con Edison—Commodity	$5
CECONY—Commodity
Transmission Congestion Contracts	$2	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
			Discount/premium to adjust auction prices for historical monthly realized settlements (b)	53.3%-144.9%


(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



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of April 1,	$(4)	$11	$2	$12
Included in earnings	5	(3)	—	(2)
Included in regulatory assets and liabilities	1	—	(1)	—
Purchases	1	5	1	2
Settlements	2	—	—	(1)
Ending balance as of June 30,	$5	$13	$2	$11



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of January 1,	$6	$20	$8	$13
Included in earnings	(2)	(15)	(1)	(5)
Included in regulatory assets and liabilities	(2)	1	(5)	1
Purchases	1	8	1	4
Settlements	2	(1)	(1)	(2)
Ending balance as of June 30,	$5	$13	$2	$11

Variable Interest Entities (Tables)

6 Months Ended

Jun. 30, 2016

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 June 30, 2016:



Project Name (a)	Generating Capacity (b) (MW 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	$184
Panoche Valley	120	20	2015	California	204
Mesquite Solar 1	83	20	2013	Arizona	105
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	68
Broken Bow II	38	25	2014	Nebraska	54
Texas Solar 4	32	25	2014	Texas	15
Pilesgrove (e)	9	n/a (d)	2010	New Jersey	18

(b) Represents Con Edison Development’s ownership interest in the project.

(d) Pilesgrove has 3-4 year Solar Renewable Energy Credit hedges in place.

(e) Carrying value and maximum exposure reduced by an $8 million impairment charge in June 2016 (included in Investment and other income on Con Edison's consolidated income statement).

- Definition

Tabular disclosure of the significant judgments and assumptions made in determining whether a variable interest (as defined) held by the entity requires the variable interest entity (VIE) (as defined) to be consolidated and (or) disclose information about its involvement with the VIE, individually or in aggregate (as applicable); the nature of restrictions, if any, on the consolidated VIE's assets and on the settlement of its liabilities reported by an entity in its statement of financial position, including the carrying amounts of such assets and liabilities; the nature of, and changes in, the risks associated with involvement in the VIE; how involvement with the VIE affects the entity's financial position, financial performance, and cash flows; the lack of recourse if creditors (or beneficial interest holders) of the consolidated VIE have no recourse to the general credit of the primary beneficiary (if applicable); the terms of arrangements, giving consideration to both explicit arrangements and implicit variable interests, if any, that could require the entity to provide financial support to the VIE, including events or circumstances that could expose the entity to a loss; the methodology used by the entity for determining whether or not it is the primary beneficiary of the variable interest entity; the significant factors considered and judgments made in determining that the power to direct the activities of a VIE that most significantly impact the VIE's economic performance are shared (as defined); the carrying amounts and classification of assets and liabilities of the VIE included in the statement of financial position; the entity's maximum exposure to loss, if any, as a result of its involvement with the VIE, including how the maximum exposure is determined and significant sources of the entity's exposure to the VIE; a comparison of the carrying amounts of the assets and liabilities and the entity's maximum exposure to loss; information about any liquidity arrangements, guarantees, and (or) other commitments by third parties that may affect the fair value or risk of the entity's variable interest in the VIE; whether or not the entity has provided financial support or other support (explicitly or implicitly) to the VIE that it was not previously contractually required to provide or whether the entity intends to provide that support, including the type and amount of the support and the primary reasons for providing the support; and supplemental information the entity determines necessary to provide.

+ References + Details

Assets Held For Sale (Tables)

6 Months Ended

Jun. 30, 2016

Discontinued Operations and Disposal Groups [Abstract]

Disposal Groups, Including Discontinued Operations

At June 30, 2016, 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		$—	$4		$4
Accounts receivable less allowance for uncollectible accounts of $2	70		—		70
Accrued unbilled revenue	79		1		80
Other assets	4		1		5
Total current assets	153		6		159
Utility plant, less accumulated depreciation of $6	—		14		14
Non-utility property, less accumulated depreciation of $13	3		—		3
Non-utility property construction work in progress	1		—		1
Regulatory assets	—		3		3
Other assets	3		—		3
Total assets held for sale	$160		$23		$183

Fair value of derivative liabilities	$34			$—	$34
Accounts payable	5		—		5
Other	3		1		4
Total current liabilities	42		1		43
Fair value of derivative liabilities	14		—		14
Long-term debt	—		3		3
Total liabilities held for sale	$56		$4		$60

- Definition

Tabular disclosure of information related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

+ References

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+ Details

Summary of Significant Accounting Policies - Earnings Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2016	Mar. 31, 2016	Jun. 30, 2015	Mar. 31, 2015	Jun. 30, 2016	Jun. 30, 2015
Accounting Policies [Abstract]
Net income	$ 232	$ 310	$ 219	$ 370	$ 542	$ 589
Weighted average common shares outstanding – basic	299.1		292.9		296.7	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.3		1.1		1.3	1.0
Adjusted weighted average common shares outstanding – diluted	300.4		294.0		298.0	293.9
Net income per common share-basic (dollars per share)	$ 0.78		$ 0.75		$ 1.83	$ 2.01
Net income per common share-diluted (dollars per share)	$ 0.77		$ 0.74		$ 1.82	$ 2.01

Summary of Significant Accounting Policies - Changes in Accumulated Other Comprehensive Income/(Loss) by Component (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	$ 13,201	$ 12,770	$ 13,061	$ 12,585
Current period OCI, net of taxes	1	1	1	6
Ending Balance	13,958	12,797	13,958	12,797
OCI before reclassifications, tax			1	(2)
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(1)	(1)	(2)	(2)
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Current period OCI, net of taxes	1	1	1	1
Accumulated Other Comprehensive Income/(Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(34)	(40)	(34)	(45)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively			(1)	3
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015	1	1	2	3
Current period OCI, net of taxes	1	1	1	6
Ending Balance	(33)	(39)	(33)	(39)
Accumulated Other Comprehensive Income/(Loss) \| CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(9)	(11)	(9)	(11)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively			0	0
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015	1	1	1	1
Current period OCI, net of taxes	1	1	1	1
Ending Balance	$ (8)	$ (10)	$ (8)	$ (10)

Regulatory Matters - Summary of Rate Plan (Detail) - USD ($) $ in Millions	1 Months Ended				6 Months Ended
	Jul. 31, 2016	Jun. 30, 2016	May 31, 2016	Apr. 30, 2016	Jun. 30, 2016
Year 1 \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount		$ 16
Public utilities, requested rate increase (decrease), amount		498
Year 1 \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount		(29)
Public utilities, requested rate increase (decrease), amount		125
Year 2 \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount		(11)
Public utilities, requested rate increase (decrease), amount		169
Year 2 \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount		13
Public utilities, requested rate increase (decrease), amount		110
Year 3 \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount		45
Public utilities, requested rate increase (decrease), amount		186
Year 3 \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount		9
Public utilities, requested rate increase (decrease), amount		$ 100
NYSPSC \| NYSPSC January 2016 Proceeding \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Return on common equity (percent)					9.75%
NYSPSC \| NYSPSC January 2016 Proceeding \| Year 1 \| CECONY \| Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount			$ 45
Return on common equity (percent)			8.60%
NYSPSC \| NYSPSC January 2016 Proceeding \| Year 1 \| CECONY \| Gas
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount			$ (25)
Return on common equity (percent)			8.60%
New Jersey Board of Public Utilities \| Rockland Electric Company \| Year 1 \| Rockland Electric Company \| Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount				$ 10
Return on common equity (percent)				10.20%
Common equity ratio (percent)				49.81%
New Jersey Board of Public Utilities \| Rockland Electric Company \| Subsequent Event \| Year 1 \| Rockland Electric Company \| Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount	$ (1)
Return on common equity (percent)	10.20%
Common equity ratio (percent)	49.71%
New Jersey Board of Public Utilities \| Rockland Electric Company \| Subsequent Event \| Year 2 \| Rockland Electric Company \| Electric
Public Utilities, General Disclosures [Line Items]
Public utilities, requested rate increase (decrease), amount	$ 9

Regulatory Matters - Additional Information (Detail) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Public Utilities, General Disclosures [Line Items]
Expected credit to customers	$ 116,000,000
Return on capital expenditures, not recoverable (up to)	55,000,000
Regulatory liabilities	1,932,000,000	$ 1,977,000,000
Prudence proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities		99,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities	1,743,000,000	1,789,000,000
CECONY \| Prudence proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities	97,000,000	$ 99,000,000
CECONY \| June 2014 Plastic Fusion Proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities	$ 18,000,000

Regulatory Matters - Regulatory Assets and Liabilities (Detail) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Regulatory assets
Regulatory assets – noncurrent	$ 7,680	$ 8,096
Regulatory assets – current	84	132
Total Regulatory Assets	7,764	8,228
Regulatory liabilities
Regulatory liabilities – noncurrent	1,932	1,977
Regulatory liabilities – current	122	115
Total Regulatory Liabilities	2,054	2,092
Allowance for cost of removal less salvage
Regulatory liabilities
Regulatory liabilities – noncurrent	708	676
Property tax reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	230	303
Pension and other postretirement benefit deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	125	76
Net unbilled revenue deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	117	109
Prudence proceeding
Regulatory liabilities
Regulatory liabilities – noncurrent		99
Unrecognized other postretirement costs
Regulatory liabilities
Regulatory liabilities – noncurrent	93	28
Base rate change deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	77	128
New York State income tax rate change
Regulatory liabilities
Regulatory liabilities – noncurrent	69	75
Variable-rate tax-exempt debt – cost rate reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	64	70
Carrying charges on repair allowance and bonus depreciation
Regulatory liabilities
Regulatory liabilities – noncurrent	51	49
Earnings sharing - electric, gas and steam
Regulatory liabilities
Regulatory liabilities – noncurrent	34	80
Net utility plant reconciliations
Regulatory liabilities
Regulatory liabilities – noncurrent	28	32
Property tax refunds
Regulatory liabilities
Regulatory liabilities – noncurrent	22	44
World Trade Center settlement proceeds
Regulatory liabilities
Regulatory liabilities – noncurrent	10	21
Other
Regulatory liabilities
Regulatory liabilities – noncurrent	207	187
Revenue decoupling mechanism
Regulatory liabilities
Regulatory liabilities – current	79	45
Refundable energy costs
Regulatory liabilities
Regulatory liabilities – current	30	64
Deferred derivative gains
Regulatory liabilities
Regulatory liabilities – current	13	6
Unrecognized pension and other postretirement costs
Regulatory assets
Regulatory assets – noncurrent	3,516	3,876
Future income tax
Regulatory assets
Regulatory assets – noncurrent	2,379	2,350
Revenue taxes
Regulatory assets
Regulatory assets – noncurrent	295	253
Deferred storm costs
Regulatory assets
Regulatory assets – noncurrent	122	185
Unamortized loss on reacquired debt
Regulatory assets
Regulatory assets – noncurrent	47	50
O&R property tax reconciliation
Regulatory assets
Regulatory assets – noncurrent	42	46
Deferred derivative losses
Regulatory assets
Regulatory assets – noncurrent	38	50
Pension and other postretirement benefits deferrals
Regulatory assets
Regulatory assets – noncurrent	35	45
Net electric deferrals
Regulatory assets
Regulatory assets – noncurrent	34	44
Surcharge for New York State assessment
Regulatory assets
Regulatory assets – noncurrent	32	44
Preferred stock redemption
Regulatory assets
Regulatory assets – noncurrent	26	26
O&R transition bond charges
Regulatory assets
Regulatory assets – noncurrent	18	21
Recoverable energy costs
Regulatory assets
Regulatory assets – noncurrent	0	16
Regulatory assets – current	9	19
Other
Regulatory assets
Regulatory assets – noncurrent	243	175
Deferred derivative losses
Regulatory assets
Regulatory assets – current	75	113
CECONY
Regulatory assets
Regulatory assets – noncurrent	7,109	7,482
Regulatory assets – current	77	121
Total Regulatory Assets	7,186	7,603
Regulatory liabilities
Regulatory liabilities – noncurrent	1,743	1,789
Regulatory liabilities – current	98	84
Total Regulatory Liabilities	1,841	1,873
CECONY \| Allowance for cost of removal less salvage
Regulatory liabilities
Regulatory liabilities – noncurrent	599	570
CECONY \| Property tax reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	230	303
CECONY \| Pension and other postretirement benefit deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	96	46
CECONY \| Net unbilled revenue deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	117	109
CECONY \| Prudence proceeding
Regulatory liabilities
Regulatory liabilities – noncurrent	97	99
CECONY \| Unrecognized other postretirement costs
Regulatory liabilities
Regulatory liabilities – noncurrent	93	28
CECONY \| Base rate change deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	77	128
CECONY \| New York State income tax rate change
Regulatory liabilities
Regulatory liabilities – noncurrent	66	72
CECONY \| Variable-rate tax-exempt debt – cost rate reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	56	60
CECONY \| Carrying charges on repair allowance and bonus depreciation
Regulatory liabilities
Regulatory liabilities – noncurrent	50	48
CECONY \| Earnings sharing - electric, gas and steam
Regulatory liabilities
Regulatory liabilities – noncurrent	30	80
CECONY \| Net utility plant reconciliations
Regulatory liabilities
Regulatory liabilities – noncurrent	28	31
CECONY \| Property tax refunds
Regulatory liabilities
Regulatory liabilities – noncurrent	22	44
CECONY \| World Trade Center settlement proceeds
Regulatory liabilities
Regulatory liabilities – noncurrent	10	21
CECONY \| Other
Regulatory liabilities
Regulatory liabilities – noncurrent	172	150
CECONY \| Revenue decoupling mechanism
Regulatory liabilities
Regulatory liabilities – current	78	45
CECONY \| Refundable energy costs
Regulatory liabilities
Regulatory liabilities – current	9	33
CECONY \| Deferred derivative gains
Regulatory liabilities
Regulatory liabilities – current	11	6
CECONY \| Unrecognized pension and other postretirement costs
Regulatory assets
Regulatory assets – noncurrent	3,361	3,697
CECONY \| Future income tax
Regulatory assets
Regulatory assets – noncurrent	2,262	2,232
CECONY \| Revenue taxes
Regulatory assets
Regulatory assets – noncurrent	281	240
CECONY \| Deferred storm costs
Regulatory assets
Regulatory assets – noncurrent	57	110
CECONY \| Unamortized loss on reacquired debt
Regulatory assets
Regulatory assets – noncurrent	44	48
CECONY \| O&R property tax reconciliation
Regulatory assets
Regulatory assets – noncurrent	0	0
CECONY \| Deferred derivative losses
Regulatory assets
Regulatory assets – noncurrent	35	46
CECONY \| Pension and other postretirement benefits deferrals
Regulatory assets
Regulatory assets – noncurrent	6	16
CECONY \| Net electric deferrals
Regulatory assets
Regulatory assets – noncurrent	34	44
CECONY \| Surcharge for New York State assessment
Regulatory assets
Regulatory assets – noncurrent	29	40
CECONY \| Preferred stock redemption
Regulatory assets
Regulatory assets – noncurrent	26	26
CECONY \| O&R transition bond charges
Regulatory assets
Regulatory assets – noncurrent	0	0
CECONY \| Recoverable energy costs
Regulatory assets
Regulatory assets – noncurrent	0	15
Regulatory assets – current	7	18
CECONY \| Other
Regulatory assets
Regulatory assets – noncurrent	226	157
CECONY \| Deferred derivative losses
Regulatory assets
Regulatory assets – current	70	103
Superfund Sites
Regulatory assets
Total Regulatory Assets	837	904
Superfund Sites \| Environmental remediation costs
Regulatory assets
Regulatory assets – noncurrent	837	904
Superfund Sites \| CECONY
Regulatory assets
Total Regulatory Assets	732	800
Superfund Sites \| CECONY \| Environmental remediation costs
Regulatory assets
Regulatory assets – noncurrent	732	800
Workers’ compensation
Regulatory assets
Total Regulatory Assets	16	11
Workers’ compensation \| Workers’ compensation
Regulatory assets
Regulatory assets – noncurrent	16	11
Workers’ compensation \| CECONY
Regulatory assets
Total Regulatory Assets	16	11
Workers’ compensation \| CECONY \| Workers’ compensation
Regulatory assets
Regulatory assets – noncurrent	$ 16	$ 11

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Detail) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Carrying Amount	$ 14,493	$ 12,745
Fair Value	16,681	13,856
CECONY
Debt Instrument [Line Items]
Carrying Amount	11,983	11,437
Fair Value	$ 13,917	$ 12,427

Capitalization - Additional Information (Detail) - USD ($)	1 Months Ended		3 Months Ended	6 Months Ended
	Jun. 30, 2016	May 31, 2016	Jun. 30, 2016	Jun. 30, 2016	Jun. 30, 2015	Feb. 29, 2016	Dec. 31, 2015
Schedule of Capitalization [Line Items]
Stock issued during the period, value			$ 702,000,000
Proceeds from long-term debt				$ 1,765,000,000	$ 238,000,000
Long-term debt, fair value	$ 16,681,000,000		16,681,000,000	16,681,000,000			$ 13,856,000,000
Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value	16,045,000,000		16,045,000,000	16,045,000,000
Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value	636,000,000		636,000,000	636,000,000
CECONY
Schedule of Capitalization [Line Items]
Proceeds from long-term debt				550,000,000	$ 0
Long-term debt, fair value	13,917,000,000		13,917,000,000	13,917,000,000			$ 12,427,000,000
CECONY \| Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value	13,281,000,000		13,281,000,000	13,281,000,000
CECONY \| Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value	636,000,000		636,000,000	636,000,000
Tax-exempt debt				636,000,000
Senior Notes \| 4.21% Senior Notes due 2041 \| Con Edison Development
Schedule of Capitalization [Line Items]
Debt Instrument, face amount						$ 218,000,000
Debt instrument, interest rate (percent)						4.21%
Senior Notes \| 4.07% Senior Notes due 2036 \| Con Edison Development
Schedule of Capitalization [Line Items]
Debt Instrument, face amount		$ 95,000,000
Debt instrument, interest rate (percent)		4.07%
Secured Debt \| 2.00% Debentures due 2021
Schedule of Capitalization [Line Items]
Debt Instrument, face amount		$ 500,000,000
Debt instrument, interest rate (percent)		2.00%
Secured Debt \| 3.85% Debentures due 2046 \| CECONY
Schedule of Capitalization [Line Items]
Debt Instrument, face amount	$ 550,000,000		$ 550,000,000	$ 550,000,000
Debt instrument, interest rate (percent)	3.85%		3.85%	3.85%
Secured Debt \| New Jersey Utility Agreement \| Con Edison Solutions
Schedule of Capitalization [Line Items]
Debt instrument, interest rate (percent)	11.18%		11.18%	11.18%
Proceeds from long-term debt	$ 2,000,000
Unsecured Debt \| Term Loan Credit Facility
Schedule of Capitalization [Line Items]
Debt Instrument, face amount	$ 400,000,000		$ 400,000,000	$ 400,000,000
Common Stock
Schedule of Capitalization [Line Items]
Stock issued during period (in shares)		10,000,000	10,000,000
Stock issued during the period, value		$ 702,000,000	$ 1,000,000
LIBOR \| Senior Notes \| 4.07% Senior Notes due 2036 \| Con Edison Development
Schedule of Capitalization [Line Items]
Debt instrument, basis spread on variable rate (percent)	1.00%

Short-Term Borrowing - Additional Information (Detail) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 708,000,000	$ 1,529,000,000
Weighted average interest rate (percent)	0.70%	0.70%
Loans outstanding under credit agreement	$ 0	$ 0
Letters of credit outstanding under the Credit Agreement	2,000,000	15,000,000
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 608,000,000	$ 1,033,000,000
Weighted average interest rate (percent)	0.70%	0.70%
Loans outstanding under credit agreement	$ 0	$ 0
Letters of credit outstanding under the Credit Agreement	$ 2,000,000

Pension Benefits - Total Periodic Benefit Costs (Detail) - Pension Benefits - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 69	$ 74	$ 138	$ 149
Interest cost on projected benefit obligation	149	144	298	287
Expected return on plan assets	(237)	(222)	(474)	(443)
Recognition of net actuarial loss	149	194	298	388
Recognition of prior service costs	1	1	2	2
NET PERIODIC BENEFIT COST	131	191	262	383
Amortization of regulatory asset	0	1	0	1
TOTAL PERIODIC BENEFIT COST	131	192	262	384
Cost capitalized	(53)	(76)	(106)	(144)
Reconciliation to rate level	13	(17)	26	(42)
Cost charged to operating expenses	91	99	182	198
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	65	70	129	139
Interest cost on projected benefit obligation	140	135	280	269
Expected return on plan assets	(225)	(210)	(449)	(420)
Recognition of net actuarial loss	141	183	282	367
Recognition of prior service costs	0	0	1	1
NET PERIODIC BENEFIT COST	121	178	243	356
Amortization of regulatory asset	0	1	0	1
TOTAL PERIODIC BENEFIT COST	121	179	243	357
Cost capitalized	(50)	(72)	(99)	(137)
Reconciliation to rate level	14	(18)	26	(42)
Cost charged to operating expenses	$ 85	$ 89	$ 170	$ 178

Pension Benefits - Additional Information (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 508
Contributions	307
CECONY \| Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	469
CECONY \| Non-qualified Supplemental Plan
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 17

Other Postretirement Benefits - Total Periodic Postretirement Benefit Costs (Detail) - Other Postretirement Benefits - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 4	$ 5	$ 9	$ 10
Interest cost on accumulated other postretirement benefit obligation	12	13	24	25
Expected return on plan assets	(19)	(20)	(38)	(39)
Recognition of net actuarial loss	1	8	2	16
Recognition of prior service cost	(5)	(5)	(10)	(10)
NET PERIODIC BENEFIT COST	(7)	1	(13)	2
Cost capitalized	2	(1)	3	(1)
Reconciliation to rate level	7	4	14	8
Cost charged to operating expenses	2	4	4	9
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	4	7	7
Interest cost on accumulated other postretirement benefit obligation	10	11	20	22
Expected return on plan assets	(17)	(17)	(34)	(34)
Recognition of net actuarial loss	1	7	1	14
Recognition of prior service cost	(3)	(4)	(7)	(7)
NET PERIODIC BENEFIT COST	(6)	1	(13)	2
Cost capitalized	2	(1)	3	(1)
Reconciliation to rate level	6	2	14	3
Cost charged to operating expenses	$ 2	$ 2	$ 4	$ 4

Other Postretirement Benefits - Additional Information (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 6

Environmental Matters - Accrued Liabilities and Regulatory Assets (Detail) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Accrued Liabilities:
Accrued Liabilities	$ 758	$ 765
Regulatory assets	7,764	8,228
Manufactured gas plant sites
Accrued Liabilities:
Accrued Liabilities	670	679
Other Superfund Sites
Accrued Liabilities:
Accrued Liabilities	88	86
Superfund Sites
Accrued Liabilities:
Accrued Liabilities	758	765
Regulatory assets	837	904
CECONY
Accrued Liabilities:
Accrued Liabilities	664	665
Regulatory assets	7,186	7,603
CECONY \| Manufactured gas plant sites
Accrued Liabilities:
Accrued Liabilities	576	579
CECONY \| Other Superfund Sites
Accrued Liabilities:
Accrued Liabilities	88	86
CECONY \| Superfund Sites
Accrued Liabilities:
Accrued Liabilities	664	665
Regulatory assets	$ 732	$ 800

Environmental Matters - Environmental Remediation Costs (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 9	$ 8	$ 12	$ 15
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 3	$ 7	$ 5	$ 12

Environmental Matters - Additional Information (Detail) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Site Contingency [Line Items]
Insurance recoveries	$ 0	$ 0	$ 0	$ 0
Manufactured gas plant sites \| Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)					$ 2,800,000,000
CECONY
Site Contingency [Line Items]
Insurance recoveries	$ 0	$ 0	$ 0	$ 0
CECONY \| Manufactured gas plant sites \| Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)					$ 2,700,000,000
Asbestos Related
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)			15 years
Asbestos Related \| CECONY
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)			15 years

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Detail) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Site Contingency [Line Items]
Regulatory assets	$ 7,764	$ 8,228
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers’ compensation
Site Contingency [Line Items]
Accrued liability	91	86
Regulatory assets	16	11
CECONY
Site Contingency [Line Items]
Regulatory assets	7,186	7,603
CECONY \| Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY \| Workers’ compensation
Site Contingency [Line Items]
Accrued liability	86	81
Regulatory assets	$ 16	$ 11

Other Material Contingencies - Additional Information (Detail)		1 Months Ended	6 Months Ended
	Mar. 12, 2014 building Person lawsuit	Jul. 31, 2007 Person	Jun. 30, 2016 USD ($) lawsuit	Jul. 31, 2016 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2014
Guarantor Obligations [Line Items]
Number of person died in steam ruptured \| Person		1
Number of suits pending against the company \| lawsuit			80
Estimated accrued liability for suits			$ 50,000,000
Number of buildings destroyed by fire \| building	2
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			$ 2,544,000,000		$ 2,856,000,000
Ownership interest, percentage						45.70%
Estimated project cost percentage			175.00%
Manhattan Explosion and Fire
Guarantor Obligations [Line Items]
Number of suits pending against the company \| lawsuit	70
Financial And Performance Guarantee For CET Gas
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 25,000,000
Financial and Performance Guarantee, Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			75,000,000
Indemnity agreements amount			70,000,000
Electric provider obligation to Public Utility Commission of Texas			$ 5,000,000
Subsequent Event \| Finance and Performance Guarantee for Consolidated Edison Solutions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure				$ 53,000,000

Other Material Contingencies - Total Guarantees (Detail) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,544	$ 2,856
Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	1,202
Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	804
Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	463
Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	75
0-3 years
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	1,809
0-3 years \| Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	619
0-3 years \| Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	672
0-3 years \| Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	443
0-3 years \| Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	75
4-10 years
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	624
4-10 years \| Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	583
4-10 years \| Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	41
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	111
Greater than 10 years \| Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	0
Greater than 10 years \| Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	91
Greater than 10 years \| Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	20
Greater than 10 years \| Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 0

Income Tax - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Income Taxes Disclosure [Line Items]
Income taxes on operating income	$ 124	$ 101	$ 288	$ 300
Effective tax rate	35.00%	32.00%	35.00%	34.00%
Income taxes refund	$ 10		$ 10
Estimated liability for uncertain tax positions	36		36
Uncertain tax positions, reasonably possible to resolve within twelve months	27		27
Uncertain tax positions, reasonably possible to resolve within twelve months, net of federal taxes	18		18
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate	36		36
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate, net of federal taxes	24		24
CECONY
Income Taxes Disclosure [Line Items]
Income taxes on operating income	$ 84	$ 101	$ 264	$ 293
Effective tax rate	34.00%	32.00%	36.00%	34.00%
Estimated liability for uncertain tax positions	$ 4		$ 4
Uncertain tax positions, reasonably possible to resolve within twelve months	4		4
Uncertain tax positions, reasonably possible to resolve within twelve months, net of federal taxes	$ 3		$ 3

Financial Information by Business Segment - Financial Data for Business Segments (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Operating revenues	$ 2,794	$ 2,788	$ 5,950	$ 6,404
Depreciation and amortization	302	276	599	555
Operating income	515	472	1,157	1,198
Other income (deductions)	11	10	12	14
Interest charges	170	162	339	323
Income taxes on operating income	128	108	299	314
Total assets	47,270	44,751	47,270	44,751	$ 45,642
Construction expenditures	736	991	1,760	1,597
CECONY
Segment Reporting Information [Line Items]
Operating revenues	2,281	2,283	4,913	5,292
Depreciation and amortization	275	254	547	511
Operating income	392	460	1,033	1,143
Other income (deductions)	2	(2)	0	(1)
Interest charges	149	146	297	290
Income taxes on operating income	87	105	269	300
Total assets	40,353	39,701	40,353	39,701	$ 40,230
Construction expenditures	571	591	1,136	1,071
CECONY \| Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	215	201	428	403
Operating income	371	422	645	700
Other income (deductions)	2	(1)	1	(1)
Interest charges	113	113	225	223
Income taxes on operating income	88	99	137	142
Total assets	30,632	30,474	30,632	30,474
Construction expenditures	338	409	720	744
CECONY \| Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	39	35	78	70
Operating income	48	54	301	294
Other income (deductions)	0	(1)	(1)	0
Interest charges	26	23	52	46
Income taxes on operating income	9	12	97	98
Total assets	7,131	6,598	7,131	6,598
Construction expenditures	205	161	365	289
CECONY \| Steam
Segment Reporting Information [Line Items]
Depreciation and amortization	21	18	41	38
Operating income	(27)	(16)	87	149
Other income (deductions)	0	0	0	0
Interest charges	10	10	20	21
Income taxes on operating income	(10)	(6)	35	60
Total assets	2,590	2,629	2,590	2,629
Construction expenditures	28	21	51	38
O&R
Segment Reporting Information [Line Items]
Depreciation and amortization	17	17	33	34
Operating income	13	(2)	66	43
Other income (deductions)	0	0	0	1
Interest charges	9	9	18	17
Income taxes on operating income	2	(4)	19	10
Total assets	2,689	2,683	2,689	2,683
Construction expenditures	37	36	68	62
O&R \| Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	13	13	24	25
Operating income	14	16	32	34
Other income (deductions)	0	0	0	1
Interest charges	6	5	12	11
Income taxes on operating income	3	4	7	9
Total assets	1,928	1,944	1,928	1,944
Construction expenditures	25	25	47	45
O&R \| Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	4	4	9	9
Operating income	(1)	(18)	34	9
Other income (deductions)	0	0	0	0
Interest charges	3	4	6	6
Income taxes on operating income	(1)	(8)	12	1
Total assets	761	739	761	739
Construction expenditures	12	11	21	17
Competitive energy businesses
Segment Reporting Information [Line Items]
Depreciation and amortization	10	6	19	11
Operating income	109	13	58	10
Other income (deductions)	7	12	9	15
Interest charges	8	2	16	3
Income taxes on operating income	36	7	9	4
Total assets	2,494	1,549	2,494	1,549
Construction expenditures	128	364	556	464
Con Edison Transmission
Segment Reporting Information [Line Items]
Operating income	(1)	0	(1)	0
Other income (deductions)	3	0	3	0
Interest charges	1	0	1	0
Income taxes on operating income	0	0	0	0
Total assets	1,043	2	1,043	2
Construction expenditures	0	0	0	0
Other
Segment Reporting Information [Line Items]
Depreciation and amortization	0	(1)	0	(1)
Operating income	2	1	1	2
Other income (deductions)	(1)	0	0	(1)
Interest charges	3	5	7	13
Income taxes on operating income	3	0	2	0
Total assets	691	816	691	816
Construction expenditures	0	0	0	0
Operating revenues
Segment Reporting Information [Line Items]
Operating revenues	2,794	2,788	5,950	6,404
Operating revenues \| CECONY
Segment Reporting Information [Line Items]
Operating revenues	2,281	2,283	4,913	5,292
Operating revenues \| CECONY \| Electric
Segment Reporting Information [Line Items]
Operating revenues	1,892	1,879	3,665	3,858
Operating revenues \| CECONY \| Gas
Segment Reporting Information [Line Items]
Operating revenues	304	308	905	963
Operating revenues \| CECONY \| Steam
Segment Reporting Information [Line Items]
Operating revenues	85	96	343	471
Operating revenues \| O&R
Segment Reporting Information [Line Items]
Operating revenues	175	178	390	411
Operating revenues \| O&R \| Electric
Segment Reporting Information [Line Items]
Operating revenues	144	162	284	318
Operating revenues \| O&R \| Gas
Segment Reporting Information [Line Items]
Operating revenues	31	16	106	93
Operating revenues \| Competitive energy businesses
Segment Reporting Information [Line Items]
Operating revenues	338	328	648	702
Operating revenues \| Other
Segment Reporting Information [Line Items]
Operating revenues	0	(1)	(1)	(1)
Inter-segment revenues \| CECONY
Segment Reporting Information [Line Items]
Operating revenues	(26)	(27)	(56)	(55)
Inter-segment revenues \| CECONY \| Electric
Segment Reporting Information [Line Items]
Operating revenues	4	5	9	9
Inter-segment revenues \| CECONY \| Gas
Segment Reporting Information [Line Items]
Operating revenues	1	1	3	3
Inter-segment revenues \| CECONY \| Steam
Segment Reporting Information [Line Items]
Operating revenues	21	21	44	43
Inter-segment revenues \| Competitive energy businesses
Segment Reporting Information [Line Items]
Operating revenues	3	(1)	9	(4)
Inter-segment revenues \| Other
Segment Reporting Information [Line Items]
Operating revenues	$ (3)	$ 1	$ (9)	$ 4

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Detail) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Net Amounts of Assets/ (Liabilities)	$ 369	$ 345
Net Amounts of Assets/ (Liabilities)	(143)	(183)
Gross Amounts of Recognized Assets/(Liabilities)	(127)	(207)
Gross Amounts Offset	19	46
Net Amounts of Assets/ (Liabilities)	(108)	(161)
Margin deposits	16	26
Fair Value of Derivative Assets, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	78	59
Gross Amounts Offset	(50)	(41)
Net Amounts of Assets/ (Liabilities)	28	18
Fair Value of Derivative Assets, Assets Held for Sale, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	45	51
Gross Amounts Offset	(42)	(50)
Net Amounts of Assets/ (Liabilities)	3	1
Fair Value of Derivative Assets, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	33	57
Gross Amounts Offset	(32)	(54)
Net Amounts of Assets/ (Liabilities)	1	3
Fair Value of Derivative Assets, Assets Held for Sale, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	13	15
Gross Amounts Offset	(10)	(15)
Net Amounts of Assets/ (Liabilities)	3	0
Fair Value of Derivative Assets
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	169	182
Gross Amounts Offset	(134)	(160)
Net Amounts of Assets/ (Liabilities)	35	22
Fair Value of Derivative Liabilities, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(129)	(144)
Gross Amounts Offset	67	78
Net Amounts of Assets/ (Liabilities)	(62)	(66)
Fair Value of Derivative Liabilities, Liabilities Held For Sale, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(76)	(115)
Gross Amounts Offset	42	50
Net Amounts of Assets/ (Liabilities)	(34)	(65)
Fair Value of Derivative Liabilities, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(67)	(102)
Gross Amounts Offset	34	63
Net Amounts of Assets/ (Liabilities)	(33)	(39)
Fair Value of Derivative Liabilities, Liabilities Held For Sale, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(24)	(28)
Gross Amounts Offset	10	15
Net Amounts of Assets/ (Liabilities)	(14)	(13)
Fair Value of Derivative Liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(296)	(389)
Gross Amounts Offset	153	206
Net Amounts of Assets/ (Liabilities)	(143)	(183)
CECONY
Derivatives, Fair Value [Line Items]
Net Amounts of Assets/ (Liabilities)	323	311
Gross Amounts of Recognized Assets/(Liabilities)	(87)	(125)
Gross Amounts Offset	23	48
Net Amounts of Assets/ (Liabilities)	(64)	(77)
Margin deposits	16	26
CECONY \| Fair Value of Derivative Assets, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	57	40
Gross Amounts Offset	(47)	(32)
Net Amounts of Assets/ (Liabilities)	10	8
CECONY \| Fair Value of Derivative Assets, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	24	48
Gross Amounts Offset	(24)	(47)
Net Amounts of Assets/ (Liabilities)	0	1
CECONY \| Fair Value of Derivative Assets
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	81	88
Gross Amounts Offset	(71)	(79)
Net Amounts of Assets/ (Liabilities)	10	9
CECONY \| Fair Value of Derivative Liabilities, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(109)	(121)
Gross Amounts Offset	65	71
Net Amounts of Assets/ (Liabilities)	(44)	(50)
CECONY \| Fair Value of Derivative Liabilities, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(59)	(92)
Gross Amounts Offset	29	56
Net Amounts of Assets/ (Liabilities)	(30)	(36)
CECONY \| Fair Value of Derivative Liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(168)	(213)
Gross Amounts Offset	94	127
Net Amounts of Assets/ (Liabilities)	$ (74)	$ (86)

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ 11	$ (2)	$ 8	$ 1
Total deferred gains/(losses)	84	(53)	(75)	(28)
Net deferred gains/(losses)	95	(55)	(67)	(27)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	27	(103)	(86)	(82)
Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	10	(2)	7	1
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	1	0	1	0
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	68	(11)	38	32
Recoverable energy costs
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(52)	(40)	(125)	(39)
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	68	(2)	12	(21)
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	9	(1)	4	2
Total deferred gains/(losses)	76	(47)	(69)	(24)
Net deferred gains/(losses)	85	(48)	(65)	(22)
CECONY \| Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	9	(1)	5	2
CECONY \| Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	0	(1)	0
CECONY \| Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	61	(10)	33	32
CECONY \| Recoverable energy costs
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(47)	(36)	(113)	(38)
CECONY \| Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	62	(1)	11	(18)
Non Utility Operating Revenue
Pre-tax gain/(loss) recognized in income
Unrealized gain (loss) on derivatives		1	(1)	(3)
Purchased power expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	45	(50)	(70)	(28)
Unrealized gain (loss) on derivatives	97	(17)	35	(5)
Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(23)	(26)	(33)	(69)
Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ 5	$ (27)	$ 17	$ 15

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Detail)	6 Months Ended
	Jun. 30, 2016 DTH MWh MW gal
Electric Energy Derivative
Derivatives, Fair Value [Line Items]
Electric Energy (MWH) \| MWh	31,244,951
Electric Capacity Derivative
Derivatives, Fair Value [Line Items]
Capacity (MW) \| MW	23,618
Natural Gas Derivative
Derivatives, Fair Value [Line Items]
Natural Gas (Dt) \| DTH	39,700,166
Refined Fuels
Derivatives, Fair Value [Line Items]
Refined fuel (gallons) \| gal	3,360,000
CECONY \| Electric Energy Derivative
Derivatives, Fair Value [Line Items]
Electric Energy (MWH) \| MWh	15,349,625
CECONY \| Electric Capacity Derivative
Derivatives, Fair Value [Line Items]
Capacity (MW) \| MW	10,200
CECONY \| Natural Gas Derivative
Derivatives, Fair Value [Line Items]
Natural Gas (Dt) \| DTH	38,830,000
CECONY \| Refined Fuels
Derivatives, Fair Value [Line Items]
Refined fuel (gallons) \| gal	3,360,000
Discontinued Operations, Held-for-sale \| Electric Energy Derivative
Derivatives, Fair Value [Line Items]
Electric Energy (MWH) \| MWh	14,519,076
Discontinued Operations, Held-for-sale \| Electric Capacity Derivative
Derivatives, Fair Value [Line Items]
Capacity (MW) \| MW	10,779
Discontinued Operations, Held-for-sale \| Natural Gas Derivative
Derivatives, Fair Value [Line Items]
Natural Gas (Dt) \| DTH	887,007

Derivative Instruments and Hedging Activities - Additional Information (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 191
Makeup of net credit exposure with commodity exchange brokers	79
Makeup of net credit exposure independent system operators	67
Makeup of net credit exposure with investment-grade counterparties	35
Makeup of net credit exposure non-investment grade/non-rated counterparties	10
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	21
Makeup of net credit exposure with commodity exchange brokers	17
Makeup of net credit exposure with investment-grade counterparties	$ 4

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Detail) $ in Millions	Jun. 30, 2016 USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 82
Collateral posted	23
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	4
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	99
Derivatives in net asset position additional collateral	20
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	4
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	68
Collateral posted	22
CECONY \| Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	3
CECONY \| Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	$ 76

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 369	$ 345
Derivative liabilities	143	183
CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	323	311
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	204	187
Derivative liabilities	4	17
Level 1 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	195	172
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	192	200
Derivative liabilities	206	286
Level 2 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	118	114
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	13	14
Derivative liabilities	8	8
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	45	47
Derivative liabilities	95	105
Commodity \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	26	35
Derivative liabilities	74	86
Commodity \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3	2
Derivative liabilities	4	16
Commodity \| Level 1 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2	1
Derivative liabilities	3	14
Commodity \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	28	25
Derivative liabilities	118	153
Commodity \| Level 2 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	14	9
Derivative liabilities	102	129
Commodity \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	9	13
Derivative liabilities	3	1
Commodity \| Level 3 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2	8
Derivative liabilities	0	0
Commodity Contract, Held For Sale
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6	1
Derivative liabilities	48	78
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	0	1
Commodity Contract, Held For Sale \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	47	63
Derivative liabilities	88	133
Commodity Contract, Held For Sale \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4	1
Derivative liabilities	5	7
Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	318	297
Other \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	297	276
Other \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	201	185
Other \| Level 1 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	193	171
Other \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	117	112
Other \| Level 2 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	104	105
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	(40)	(56)
Derivative liabilities	(75)	(128)
Netting Adjustments \| Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	5	7
Derivative liabilities	(30)	(65)
Netting Adjustments \| Commodity \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	8	17
Derivative liabilities	(31)	(57)
Netting Adjustments \| Commodity Contract, Held For Sale
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(45)	(63)
Derivative liabilities	(45)	(63)
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 - Schedule of Commodity Derivatives (Detail) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($) $ / 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	52.80%
Minimum \| Discount/premium to adjust auction prices for historical monthly realized settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	53.30%
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) \| $ / MWh	0.86
Minimum \| Forward Energy Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH/Dt) \| $ / MWh	19.50
Minimum \| Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH/Dt) \| $ / kW-month	1.65
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	59.40%
Maximum \| Discount/premium to adjust auction prices for historical monthly realized settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	144.90%
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) \| $ / MWh	2.53
Maximum \| Forward Energy Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH/Dt) \| $ / MWh	86.50
Maximum \| Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH/Dt) \| $ / kW-month	12.25
Level 3
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ 5
Level 3 \| Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	2
Level 3 \| Transmission Congestion Contracts/Financial Transmission Rights
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ 3
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	52.80%
CECONY \| Minimum \| Discount/premium to adjust auction prices for historical monthly realized settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	53.30%
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	59.40%
CECONY \| Maximum \| Discount/premium to adjust auction prices for historical monthly realized settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	144.90%
CECONY \| Level 3 \| Transmission Congestion Contracts
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ 2

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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ (4)	$ 11	$ 6	$ 20
Included in earnings	5	(3)	(2)	(15)
Included in regulatory assets and liabilities	1	0	(2)	1
Purchases	1	5	1	8
Settlements	2	0	2	(1)
Ending balance	5	13	5	13
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	2	12	8	13
Included in earnings	0	(2)	(1)	(5)
Included in regulatory assets and liabilities	(1)	0	(5)	1
Purchases	1	2	1	4
Settlements	0	(1)	(1)	(2)
Ending balance	$ 2	$ 11	$ 2	$ 11

Fair Value Measurements - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
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)	$ 7	$ 1	$ 3	$ (4)
Competitive energy businesses
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative liabilities	$ 5	$ (1)	$ (2)	$ (10)

Variable Interest Entities - Additional Information (Detail) - CECONY	12 Months Ended
	Dec. 31, 2015 counterparty entity
Variable Interest Entity [Line Items]
Number of potential VIEs, long-term electricity purchase agreements \| entity	2
Number of counterparties \| counterparty	2

Variable Interest Entities - Summary of VIEs (Detail)	6 Months Ended
Variable Interest Entities - Summary of VIEs (Detail)	Jun. 30, 2016 USD ($) MW
Pilesgrove (e) \| Minimum \| Solar Renewable Energy Credit Hedge
Variable Interest Entity [Line Items]
Renewable Energy Credit	3 years
Pilesgrove (e) \| Maximum \| Solar Renewable Energy Credit Hedge
Variable Interest Entity [Line Items]
Renewable Energy Credit	4 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 \| 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	2014
Maximum exposure to loss	$ 184,000,000
Variable Interest Entity, Not Primary Beneficiary \| Panoche Valley \| California
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) \| MW	120
Power Purchase Agreement Term (in Years)	20 years
Year of Initial Investment	2015
Maximum exposure to loss	$ 204,000,000
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	2013
Maximum exposure to loss	$ 105,000,000
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	2013
Maximum exposure to loss	$ 84,000,000
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	2012
Maximum exposure to loss	$ 68,000,000
Variable Interest Entity, Not Primary Beneficiary \| Broken Bow II \| Nebraska
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) \| MW	38
Power Purchase Agreement Term (in Years)	25 years
Year of Initial Investment	2014
Maximum exposure to loss	$ 54,000,000
Variable Interest Entity, Not Primary Beneficiary \| Pilesgrove (e) \| New Jersey
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) \| MW	9
Year of Initial Investment	2010
Maximum exposure to loss	$ 18,000,000
Impairment of solar electric production investment	$ 8,000,000
Variable Interest Entity, Primary Beneficiary \| Texas Solar 4
Variable Interest Entity [Line Items]
Percentage of variable interests	80.00%
VIEs, noncontrolling interest	$ 8,000,000
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	2014
Maximum exposure to loss	$ 15,000,000

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	May 31, 2016	Jan. 31, 2016	Dec. 31, 2014
Related Party Transaction [Line Items]
Ownership interest, percentage							45.70%
Costs of gas purchased	$ 81	$ 89	$ 239	$ 351
CECONY
Related Party Transaction [Line Items]
Costs of gas purchased	$ 51	$ 54	183	$ 252
CET Electric
Related Party Transaction [Line Items]
Ownership interest, percentage					45.70%	45.70%
Stagecoach Gas Services LLC \| CECONY \| Equity Method Investee \| Purchased Power Costs
Related Party Transaction [Line Items]
Costs of gas purchased			$ 3

Assets Held For Sale (Details) - USD ($) $ in Millions		1 Months Ended	6 Months Ended	12 Months Ended
Assets Held For Sale (Details) - USD ($) $ in Millions	Sep. 30, 2015	Oct. 31, 2015	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total current assets			$ 183		$ 157
Non-utility property, less accumulated depreciation of $13			859		832
Total current liabilities			60		$ 89
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			4
Accounts receivable less allowance for uncollectible accounts of $2			70
Accrued unbilled revenue			80
Other assets			5
Total current assets			159
Utility plant, less accumulated depreciation of $6			14
Non-utility property, less accumulated depreciation of $13			3
Non-utility property construction work in progress			1
Regulatory assets			3
Other assets			3
Total assets held for sale			183
Fair value of derivative liabilities			34
Accounts payable			5
Other			4
Total current liabilities			43
Fair value of derivative liabilities			14
Long-term debt			3
Total liabilities held for sale			60
Allowance for uncollectible accounts			2
Depreciation, utility plant			6
Depreciation, non-utility property			13
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 less allowance for uncollectible accounts of $2			70
Accrued unbilled revenue			79
Other assets			4
Total current assets			153
Utility plant, less accumulated depreciation of $6			0
Non-utility property, less accumulated depreciation of $13			3
Non-utility property construction work in progress			1
Regulatory assets			0
Other assets			3
Total assets held for sale			160
Fair value of derivative liabilities			34
Accounts payable			5
Other			3
Total current liabilities			42
Fair value of derivative liabilities			14
Long-term debt			0
Total liabilities held for sale			56
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
Impairment of long-lived assets to be disposed of	$ 5
Impairment of long-lived assets to be disposed of, net of taxes	$ 3
Cash and temporary cash investments			4
Accounts receivable less allowance for uncollectible accounts of $2			0
Accrued unbilled revenue			1
Other assets			1
Total current assets			6
Utility plant, less accumulated depreciation of $6			14
Non-utility property, less accumulated depreciation of $13			0
Non-utility property construction work in progress			0
Regulatory assets			3
Other assets			0
Total assets held for sale			23
Fair value of derivative liabilities			0
Accounts payable			0
Other			1
Total current liabilities			1
Fair value of derivative liabilities			0
Long-term debt			3
Total liabilities held for sale			$ 4
Scenario, Forecast \| Retail Electric Supply Business \| 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				$ 200

Acquisitions, Investments and Dispositions (Details) $ in Millions	1 Months Ended			12 Months Ended
	Jun. 30, 2016 USD ($)	May 31, 2016 USD ($)	Jan. 31, 2016 USD ($) MW	Dec. 31, 2018 USD ($)	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Ownership interest, percentage					45.70%
Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership (percent)			12.50%
Payments to acquire equity method investments			$ 18
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership (percent)	50.00%
Payments to acquire equity method investments	$ 945
Texas Solar 7 \| Texas
Schedule of Equity Method Investments [Line Items]
Generating capacity \| MW			106
Payments to acquire business			$ 227
Non-utility construction work in progress			218
Other receivables			9
Electric \| Texas Solar 7 \| Texas
Schedule of Equity Method Investments [Line Items]
Consideration transferred			$ 375
Scenario, Forecast \| Gas \| Minimum \| Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments				$ 3,000
Scenario, Forecast \| Gas \| Maximum \| Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments				$ 3,500
CET Electric
Schedule of Equity Method Investments [Line Items]
Ownership interest, percentage		45.70%	45.70%
TOTS Project \| NY Transco \| CET Electric
Schedule of Equity Method Investments [Line Items]
Contributions to affiliates		$ 48
Purchase Price of TOTS Project Transfer \| NY Transco \| CET Electric
Schedule of Equity Method Investments [Line Items]
Related party transaction, amount of transaction		122
Lease Payments \| NY Transco \| CET Electric
Schedule of Equity Method Investments [Line Items]
Expenses from transactions with related party		$ 8