Document and Entity Information - shares	6 Months Ended
Document and Entity Information - shares	Jun. 30, 2017	Jul. 31, 2017
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2017
Document Fiscal Year Focus	2017
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		305,674,488
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, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
OPERATING REVENUES
Electric	$ 1,965	$ 2,035	$ 3,899	$ 3,947
Gas	435	336	1,297	1,012
Steam	88	85	385	343
Non-utility	145	338	280	648
TOTAL OPERATING REVENUES	2,633	2,794	5,861	5,950
OPERATING EXPENSES
Purchased power	408	558	793	1,249
Fuel	38	33	139	104
Gas purchased for resale	149	81	470	239
Other operations and maintenance	773	820	1,553	1,607
Depreciation and amortization	332	302	662	599
Taxes, other than income taxes	511	485	1,052	995
TOTAL OPERATING EXPENSES	2,211	2,279	4,669	4,793
Gain on sale of solar electric production project	1	0	1	0
OPERATING INCOME	423	515	1,193	1,157
OTHER INCOME (DEDUCTIONS)
Investment income	20	7	39	7
Other income	17	8	23	12
Allowance for equity funds used during construction	2	2	5	4
Other deductions	(5)	(6)	(7)	(11)
TOTAL OTHER INCOME	34	11	60	12
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	457	526	1,253	1,169
INTEREST EXPENSE
Interest on long-term debt	179	167	356	330
Other interest	3	5	7	12
Allowance for borrowed funds used during construction	(2)	(2)	(3)	(3)
NET INTEREST EXPENSE	180	170	360	339
INCOME BEFORE INCOME TAX EXPENSE	277	356	893	830
INCOME TAX EXPENSE	102	124	330	288
NET INCOME	$ 175	$ 232	$ 563	$ 542
Net income per common share-basic (dollars per share)	$ 0.57	$ 0.78	$ 1.84	$ 1.83
Net income per common share-diluted (dollars per share)	0.57	0.77	1.84	1.82
DIVIDENDS DECLARED PER COMMON SHARE (dollars per share)	$ 0.69	$ 0.67	$ 1.38	$ 1.34
AVERAGE NUMBER OF SHARES OUTSTANDING-BASIC (IN MILLIONS) (shares)	305.4	299.1	305.3	296.7
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS) (shares)	306.8	300.4	306.7	298.0
CECONY
OPERATING REVENUES
Electric	$ 1,817	$ 1,892	$ 3,610	$ 3,665
Gas	388	304	1,153	905
Steam	88	85	386	343
TOTAL OPERATING REVENUES	2,293	2,281	5,149	4,913
OPERATING EXPENSES
Purchased power	363	369	710	721
Fuel	38	33	139	104
Gas purchased for resale	84	51	314	183
Other operations and maintenance	638	701	1,301	1,381
Depreciation and amortization	296	275	591	547
Taxes, other than income taxes	487	460	1,003	944
TOTAL OPERATING EXPENSES	1,906	1,889	4,058	3,880
OPERATING INCOME	387	392	1,091	1,033
OTHER INCOME (DEDUCTIONS)
Investment income	3	1	7	2
Allowance for equity funds used during construction	2	2	5	4
Other deductions	(4)	(1)	(6)	(6)
TOTAL OTHER INCOME	1	2	6	0
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	388	394	1,097	1,033
INTEREST EXPENSE
Interest on long-term debt	151	146	301	290
Other interest	4	4	8	9
Allowance for borrowed funds used during construction	(1)	(1)	(3)	(2)
NET INTEREST EXPENSE	154	149	306	297
INCOME BEFORE INCOME TAX EXPENSE	234	245	791	736
INCOME TAX EXPENSE	91	84	309	264
NET INCOME	$ 143	$ 161	$ 482	$ 472

Consolidated Statement of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
NET INCOME	$ 175	$ 232	$ 563	$ 542
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	1	0	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	0	1
COMPREHENSIVE INCOME	176	233	563	543
CECONY
NET INCOME	143	161	482	472
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	0	1	0	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	0	1	0	1
COMPREHENSIVE INCOME	$ 143	$ 162	$ 482	$ 473

Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
OPERATING ACTIVITIES
Net income	$ 563	$ 542
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	662	599
Deferred income taxes	359	268
Rate case amortization and accruals	(62)	(112)
Common equity component of allowance for funds used during construction	(5)	(4)
Net derivative (gains)/losses	2	(33)
(Gain)/Loss on sale of solar electric production project	(1)	0
Other non-cash items, net	(43)	42
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	128	101
Materials and supplies, including fuel oil and gas in storage	(18)	29
Other receivables and other current assets	12	(38)
Income taxes receivable	29	151
Prepayments	(36)	(15)
Accounts payable	(94)	(21)
Pensions and retiree benefits obligations, net	213	302
Pensions and retiree benefits contributions	(283)	(307)
Accrued taxes	(22)	(16)
Accrued interest	(18)	3
Superfund and environmental remediation costs, net	(6)	60
Distributions from equity investments	52	24
System benefit charge	132	151
Deferred charges, noncurrent assets and other regulatory assets	(45)	(98)
Deferred credits and other regulatory liabilities	(17)	75
Other current and noncurrent liabilities	72	(72)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,574	1,631
INVESTING ACTIVITIES
Utility construction expenditures	(1,425)	(1,344)
Cost of removal less salvage	(122)	(95)
Non-utility construction expenditures	(225)	(331)
Proceeds from the transfer of assets to NY Transco	0	122
Proceeds from sale of assets	34	0
Restricted cash	28	(6)
Other investing activities	24	(82)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,703)	(2,986)
FINANCING ACTIVITIES
Net issuance/(payment) of short-term debt	(18)	(821)
Issuance of long-term debt	997	1,765
Retirement of long-term debt	(426)	(6)
Debt issuance costs	(11)	(15)
Common stock dividends	(398)	(378)
Issuance of common shares - public offering	0	702
Issuance of common shares for stock plans	25	27
Distribution to noncontrolling interest	0	(1)
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	169	1,273
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	40	(82)
BALANCE AT BEGINNING OF PERIOD	776	944
BALANCE AT END OF PERIOD	816	862
Cash paid/(received) during the period for:
Interest	372	318
Income taxes	(35)	(142)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	308	254
Issuance of common shares for dividend reinvestment	23	23
Electric and Gas Transmission Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(16)	(79)
Renewable Electric Production Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(1)	(1,171)
CECONY
OPERATING ACTIVITIES
Net income	482	472
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	591	547
Deferred income taxes	326	283
Rate case amortization and accruals	(72)	(120)
Common equity component of allowance for funds used during construction	(5)	(4)
Other non-cash items, net	(18)	15
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	125	102
Materials and supplies, including fuel oil and gas in storage	(4)	18
Other receivables and other current assets	56	(64)
Accounts receivable from affiliated companies	17	92
Prepayments	(20)	3
Accounts payable	(60)	(54)
Accounts payable to affiliated companies	3	5
Pensions and retiree benefits obligations, net	191	287
Pensions and retiree benefits contributions	(281)	(306)
Accrued taxes	(17)	(15)
Accrued interest	0	(3)
Superfund and environmental remediation costs, net	(4)	67
System benefit charge	120	138
Accrued taxes to affiliated companies	(119)	(2)
Deferred charges, noncurrent assets and other regulatory assets	(72)	(100)
Deferred credits and other regulatory liabilities	11	89
Other current and noncurrent liabilities	(16)	(51)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,234	1,399
INVESTING ACTIVITIES
Utility construction expenditures	(1,341)	(1,268)
Cost of removal less salvage	(119)	(92)
Proceeds from the transfer of assets to NY Transco	0	122
Restricted cash	0	13
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,460)	(1,225)
FINANCING ACTIVITIES
Net issuance/(payment) of short-term debt	150	(425)
Issuance of long-term debt	500	550
Debt issuance costs	(6)	(6)
Capital contribution by parent	45	51
Dividend to parent	(398)	(372)
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	291	(202)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	65	(28)
BALANCE AT BEGINNING OF PERIOD	702	843
BALANCE AT END OF PERIOD	767	815
Cash paid/(received) during the period for:
Interest	296	285
Income taxes	86	(117)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$ 234	$ 196

Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
CURRENT ASSETS
Cash and temporary cash investments	$ 816	$ 776
Accounts receivable - customers, less allowance for uncollectible accounts	984	1,106
Other receivables, less allowance for uncollectible accounts	165	195
Income taxes receivable	50	79
Accrued unbilled revenue	436	447
Fuel oil, gas in storage, materials and supplies, at average cost	357	339
Prepayments	195	159
Regulatory assets	77	100
Restricted cash	26	54
Other current assets	174	151
TOTAL CURRENT ASSETS	3,280	3,406
INVESTMENTS	1,961	1,921
UTILITY PLANT, AT ORIGINAL COST
General	2,844	2,719
TOTAL	41,463	40,411
Less: Accumulated depreciation	8,738	8,541
Net	32,725	31,870
Construction work in progress	1,212	1,175
NET UTILITY PLANT	33,937	33,045
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	1,535	1,482
Construction work in progress	779	689
NET PLANT	36,251	35,216
OTHER NONCURRENT ASSETS
Goodwill	428	428
Intangible assets, less accumulated amortization of $10 and $6 in 2017 and 2016, respectively	116	124
Regulatory assets	6,935	7,024
Other deferred charges and noncurrent assets	128	136
TOTAL OTHER NONCURRENT ASSETS	7,607	7,712
TOTAL ASSETS	49,099	48,255
CURRENT LIABILITIES
Long-term debt due within one year	637	39
Notes payable	1,036	1,054
Accounts payable	973	1,147
Customer deposits	345	352
Accrued taxes	42	64
Accrued interest	132	150
Accrued wages	103	101
Fair value of derivative liabilities	64	77
Regulatory liabilities	64	128
System benefit charge	566	434
Other current liabilities	367	297
TOTAL CURRENT LIABILITIES	4,329	3,843
NONCURRENT LIABILITIES
Provision for injuries and damages	171	160
Pensions and retiree benefits	1,652	1,847
Superfund and other environmental costs	745	753
Asset retirement obligations	252	246
Fair value of derivative liabilities	74	40
Deferred income taxes and unamortized investment tax credits	10,549	10,205
Regulatory liabilities	1,886	1,905
Other deferred credits and noncurrent liabilities	240	215
TOTAL NONCURRENT LIABILITIES	15,569	15,371
LONG-TERM DEBT	14,703	14,735
EQUITY
Common shareholders’ equity	14,490	14,298
Noncontrolling interest	8	8
TOTAL EQUITY (See Statement of Equity)	14,498	14,306
TOTAL LIABILITIES AND EQUITY	49,099	48,255
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	28,339	27,747
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	7,828	7,524
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,452	2,421
CECONY
CURRENT ASSETS
Cash and temporary cash investments	767	702
Accounts receivable - customers, less allowance for uncollectible accounts	914	1,032
Other receivables, less allowance for uncollectible accounts	78	81
Accrued unbilled revenue	400	399
Accounts receivable from affiliated companies	92	109
Fuel oil, gas in storage, materials and supplies, at average cost	274	270
Prepayments	120	100
Regulatory assets	68	90
Restricted cash	2	2
Other current assets	46	95
TOTAL CURRENT ASSETS	2,761	2,880
INVESTMENTS	361	315
UTILITY PLANT, AT ORIGINAL COST
General	2,597	2,490
TOTAL	38,831	37,847
Less: Accumulated depreciation	8,017	7,836
Net	30,814	30,011
Construction work in progress	1,140	1,104
NET UTILITY PLANT	31,954	31,115
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	4	4
NET PLANT	31,958	31,119
OTHER NONCURRENT ASSETS
Regulatory assets	6,404	6,473
Other deferred charges and noncurrent assets	64	69
TOTAL OTHER NONCURRENT ASSETS	6,468	6,542
TOTAL ASSETS	41,548	40,856
CURRENT LIABILITIES
Long-term debt due within one year	600	0
Notes payable	750	600
Accounts payable	756	876
Accounts payable to affiliated companies	13	10
Customer deposits	333	336
Accrued taxes	33	50
Accrued taxes to affiliated companies	0	119
Accrued interest	111	111
Accrued wages	94	91
Fair value of derivative liabilities	49	66
Regulatory liabilities	42	90
System benefit charge	518	398
Other current liabilities	206	242
TOTAL CURRENT LIABILITIES	3,505	2,989
NONCURRENT LIABILITIES
Provision for injuries and damages	165	154
Pensions and retiree benefits	1,318	1,544
Superfund and other environmental costs	651	655
Asset retirement obligations	231	227
Fair value of derivative liabilities	66	33
Deferred income taxes and unamortized investment tax credits	9,793	9,450
Regulatory liabilities	1,686	1,712
Other deferred credits and noncurrent liabilities	205	190
TOTAL NONCURRENT LIABILITIES	14,115	13,965
LONG-TERM DEBT	11,970	12,073
EQUITY
Common shareholders’ equity	11,958	11,829
TOTAL LIABILITIES AND EQUITY	41,548	40,856
CECONY \| Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	26,687	26,122
CECONY \| Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	7,095	6,814
CECONY \| Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,452	$ 2,421

Consolidated Balance Sheet (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Accounts receivable - customers, allowance for uncollectible accounts	$ 63	$ 69
Other receivables, allowance for uncollectible accounts	8	14
Non-utility property, accumulated depreciation	170	140
Intangible assets, accumulated amortization	10	6
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	58	65
Other receivables, allowance for uncollectible accounts	7	13
Non-utility property, accumulated depreciation	$ 25	$ 25

Consolidated Statement of Equity/Shareholder's Equity (Unaudited) - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Additional Paid-In Capital	Retained Earnings	Treasury Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Noncontrolling Interest	CECONY	CECONY Common Stock	CECONY Additional Paid-In Capital	CECONY Retained Earnings	CECONY Repurchased Con Edison Stock	CECONY Capital Stock Expense	CECONY Accumulated Other Comprehensive Income/(Loss)
Beginning Balance (in shares) at Dec. 31, 2015		293			23					235
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									$ 11,415	$ 589	$ 4,247	$ 7,611	$ (962)	$ (61)	(9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	310			310					310			310
Common stock dividends	(197)			(197)					(186)			(186)
Issuance of common shares for stock plans (in shares)		1
Issuance of common shares for stock plans	28		28
Capital contribution by parent									23		23
Other comprehensive income (loss)	0								0						0
Noncontrolling interest	(1)							(1)
Ending Balance (in shares) at Mar. 31, 2016		294			23					235
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)	8							(9)
Beginning Balance (in shares) at Dec. 31, 2015		293			23					235
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									11,415	$ 589	4,247	7,611	(962)	(61)	(9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	542								472
Other comprehensive income (loss)	1								1
Ending Balance (in shares) at Jun. 30, 2016		304			23					235
Ending Balance at Jun. 30, 2016									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)
Beginning Balance (in shares) at Mar. 31, 2016		294			23					235
Beginning Balance at Mar. 31, 2016	13,201	$ 32	5,058	9,236	$ (1,038)	(61)	(34)	8							(9)
Beginning Balance at Mar. 31, 2016									11,562	$ 589	4,270	7,735	(962)	(61)	(9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	232			232					161			161
Common stock dividends	(204)			(204)					(186)			(186)
Issuance of common shares for stock plans (in shares)
Issuance of common shares for stock plans	26		26
Issuance of common shares - public offering (in shares)		10
Issuance of common shares - public offering	702	$ 1	723			(22)
Capital contribution by parent									28		28
Other comprehensive income (loss)	1						1		1						1
Noncontrolling interest	0
Ending Balance (in shares) at Jun. 30, 2016		304			23					235
Ending Balance at Jun. 30, 2016									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)
Beginning Balance (in shares) at Dec. 31, 2016		305			23					235
Beginning Balance at Dec. 31, 2016	14,306	$ 33	5,854	9,559	$ (1,038)	(83)	(27)	8							(7)
Beginning Balance at Dec. 31, 2016	14,298								11,829	$ 589	4,347	7,923	(962)	(61)	(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	388			388					339			339
Common stock dividends	(211)			(211)					(199)			(199)
Issuance of common shares for stock plans	24		24
Capital contribution by parent									22		22
Other comprehensive income (loss)	(1)						(1)		0
Noncontrolling interest	0
Ending Balance (in shares) at Mar. 31, 2017		305			23					235
Ending Balance at Mar. 31, 2017									11,991	$ 589	4,369	8,063	(962)	(61)	(7)
Ending Balance at Mar. 31, 2017	14,506	$ 33	5,878	9,736	$ (1,038)	(83)	(28)	8							(7)
Beginning Balance (in shares) at Dec. 31, 2016		305			23					235
Beginning Balance at Dec. 31, 2016	14,306	$ 33	5,854	9,559	$ (1,038)	(83)	(27)	8							(7)
Beginning Balance at Dec. 31, 2016	14,298								11,829	$ 589	4,347	7,923	(962)	(61)	(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	563								482
Other comprehensive income (loss)	0								0
Ending Balance (in shares) at Jun. 30, 2017		306			23					235
Ending Balance at Jun. 30, 2017	14,490								11,958	$ 589	4,392	8,007	(962)	(61)	(7)
Ending Balance at Jun. 30, 2017	14,498	$ 33	5,904	9,701	$ (1,038)	(83)	(27)	8							(7)
Beginning Balance (in shares) at Mar. 31, 2017		305			23					235
Beginning Balance at Mar. 31, 2017	14,506	$ 33	$ 5,878	9,736	$ (1,038)	(83)	(28)	8							(7)
Beginning Balance at Mar. 31, 2017									11,991	$ 589	4,369	8,063	(962)	(61)	(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	175			175					143			143
Common stock dividends	(210)			(210)					(199)			(199)
Issuance of common shares for stock plans (in shares)			1
Issuance of common shares for stock plans	26		$ 26
Capital contribution by parent									23		23
Other comprehensive income (loss)	1						1		0
Noncontrolling interest	0
Ending Balance (in shares) at Jun. 30, 2017		306			23					235
Ending Balance at Jun. 30, 2017	14,490								$ 11,958	$ 589	$ 4,392	$ 8,007	$ (962)	$ (61)	(7)
Ending Balance at Jun. 30, 2017	$ 14,498	$ 33	$ 5,904	$ 9,701	$ (1,038)	$ (83)	$ (27)	$ 8							$ (7)

General	6 Months Ended
General	Jun. 30, 2017
Accounting Policies [Abstract]
General	General These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Orange and Rockland Utilities, Inc. (O&R), Con Edison Clean Energy Businesses, Inc. (together with its subsidiaries, the Clean Energy Businesses) and Con Edison Transmission, Inc. (together with its subsidiaries, Con Edison Transmission) in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R. As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself. 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, 2016 and their separate unaudited financial statements (including the combined notes thereto) included in Part 1, Item 1 of their combined Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017. 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 subsidiary, provides electric service in southeastern New York and northern New Jersey and gas service in southeastern New York. Con Edison Clean Energy Businesses, Inc. has three subsidiaries: Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company that provides energy-related products and services to retail customers. Con Edison Transmission, Inc. 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, 2017

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Earnings Per Common Share

Con Edison presents basic and diluted earnings per share on the face of its consolidated income statement. Basic earnings per share (EPS) are calculated by dividing earnings available to common shareholders (“Net income” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.

Potentially dilutive securities for Con Edison consist of restricted stock units, deferred stock units and stock options for which the average market price of the common shares for the period was greater than the exercise price.

For the three and six months ended June 30, 2017 and 2016, basic and diluted 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)	2017	2016	2017	2016
Net income	$175	$232	$563	$542
Weighted average common shares outstanding – basic	305.4	299.1	305.3	296.7
Add: Incremental shares attributable to effect of potentially dilutive securities	1.4	1.3	1.4	1.3
Adjusted weighted average common shares outstanding – diluted	306.8	300.4	306.7	298.0
Net Income per common share – basic	$0.57	$0.78	$1.84	$1.83
Net Income per common share – diluted	$0.57	$0.77	$1.84	$1.82

The computation of diluted EPS for the six months ended June 30, 2016 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect.

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

For the three and six months ended June 30, 2017 and 2016, 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)	2017	2016	2017	2016
Beginning balance, accumulated OCI, net of taxes (a)	$(28)	$(34)	$(7)	$(9)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2017 and 2016 (a)(b)	1	1	—	1
Current period OCI, net of taxes	1	1	—	1
Ending balance, accumulated OCI, net of taxes	$(27)	$(33)	$(7)	$(8)



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Beginning balance, accumulated OCI, net of taxes (a)	$(27)	$(34)	$(7)	$(9)
OCI before reclassifications, net of tax of $1 for Con Edison in 2017 and 2016	(2)	(1)	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2017 and 2016 (a)(b)	2	2	—	1
Current period OCI, net of taxes	—	1	—	1
Ending balance, accumulated OCI, net of taxes	$(27)	$(33)	$(7)	$(8)


(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, 2017

Regulated Operations [Abstract]

Regulatory Matters

Rate Plans

Rockland Electric Company (RECO)

In February 2017, the New Jersey Board of Public Utilities (NJBPU) approved a stipulation of settlement for a RECO electric rate plan commencing March 2017. The following table contains a summary of the electric rate plan.



RECO
Effective period		March 2017 (a)
Base rate changes		Yr. 1 - $1.7 million
Amortization to income of net regulatory (assets) and liabilities		$0.2 million over three years and continuation of $(25.6) million of deferred storm costs over four years expiring July 31, 2018 (b)
Recoverable energy costs		Current rate recovery of purchased power costs.
Cost reconciliations		None
Average rate base		Yr. 1 - $178.7 million
Weighted average cost of capital (after-tax)		7.47 percent
Authorized return on common equity		9.6 percent
Cost of long-term debt		5.37 percent
Common equity ratio		49.7 percent


(a)	Effective until a new rate plan approved by the NJBPU goes into effect.


(b)	In January 2016, the NJBPU approved RECO’s plan to spend $15.7 million in capital over three years to harden its electric system against storms, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge.

In January 2017, RECO filed a request with FERC for an increase to its annual transmission revenue requirement from $11.8 million to $19.7 million. The filing reflects a return on common equity of 10.7 percent and a common equity ratio of 48 percent.

Other Regulatory Matters

At its August 2, 2017 meeting, the New York State Public Service Commission (NYSPSC) voted to issue an order in its proceeding investigating an April 21, 2017 Metropolitan Transportation Authority (MTA) subway power outage. The NYSPSC indicated that the outage resulted from a failure of CECONY’s electricity supply to a subway station and led to a loss of the subway signals. The NYSPSC also indicated that the company’s failure to document the rerouting of secondary services to the MTA facility significantly delayed repair. The company anticipates that, pursuant to the NYSPSC order, it will be required to take certain actions, including performing inspections of electrical equipment that serves the MTA system, analyzing power supply and power quality events affecting the MTA’s signaling services, providing new monitoring and other equipment and filing monthly reports with the NYSPSC on all of the company's activities related to the MTA system. In July 2017, the Chairman of the NYSPSC notified the company that the April 21, 2017 subway power outage incident will likely result in a prudence review of the reasonableness of CECONY’s actions and conduct. The company does not anticipate that the NYSPSC order will commence a prudence review or address cost recovery. The company is unable to estimate the amount or range of its possible costs related to this matter.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at June 30, 2017 and December 31, 2016 were comprised of the following items:



	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Regulatory assets
Unrecognized pension and other postretirement costs	$2,768	$2,874	$2,612	$2,730
Future income tax	2,413	2,439	2,302	2,325
Environmental remediation costs	807	823	697	711
Revenue taxes	327	295	311	280
Deferred derivative losses	77	48	70	42
Pension and other postretirement benefits deferrals	59	38	32	7
Municipal infrastructure support costs	54	44	54	44
Deferred storm costs	44	56	—	3
Unamortized loss on reacquired debt	40	43	38	41
Indian Point Energy Center program costs	40	50	40	50
Surcharge for New York State assessment	32	28	30	26
O&R property tax reconciliation	32	37	—	—
Brooklyn Queens demand management program	26	29	26	29
Preferred stock redemption	25	25	25	25
Net electric deferrals	17	24	17	24
Recoverable energy costs	15	42	15	38
Workers’ compensation	14	13	14	13
O&R transition bond charges	12	15	—	—
Other	133	101	121	85
Regulatory assets – noncurrent	6,935	7,024	6,404	6,473
Deferred derivative losses	71	91	65	86
Recoverable energy costs	6	9	3	4
Regulatory assets – current	77	100	68	90
Total Regulatory Assets	$7,012	$7,124	$6,472	$6,563
Regulatory liabilities
Allowance for cost of removal less salvage	$786	$755	$661	$641
Pension and other postretirement benefit deferrals	206	193	177	162
Net unbilled revenue deferrals	164	145	164	145
Property tax reconciliation	148	178	148	178
Unrecognized other postretirement costs	88	60	88	60
Settlement of prudence proceeding	80	95	80	95
Carrying charges on repair allowance and bonus depreciation	55	68	54	67
New York State income tax rate change	53	61	52	60
Variable-rate tax-exempt debt – cost rate reconciliation	43	55	38	48
Base rate change deferrals	31	40	31	40
Settlement of gas proceedings	27	27	27	27
Earnings sharing - electric, gas and steam	22	39	13	28
Net utility plant reconciliations	12	16	10	15
Other	171	173	143	146
Regulatory liabilities – noncurrent	1,886	1,905	1,686	1,712
Refundable energy costs	29	29	10	5
Revenue decoupling mechanism	29	71	27	61
Deferred derivative gains	6	28	5	24
Regulatory liabilities – current	64	128	42	90
Total Regulatory Liabilities	$1,950	$2,033	$1,728	$1,802

Capitalization

6 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

Capitalization

In March 2017, Con Edison issued $400 million aggregate principal amount of 2.00 percent debentures, due 2020, and prepaid the $400 million variable rate term loan that was to mature in 2018. Also, in March 2017, a Con Edison Development subsidiary issued $97 million aggregate principal amount of 4.45 percent senior notes, due 2042, secured by the company’s Upton County Solar project. In June 2017, CECONY issued $500 million aggregate principal amount of 3.875 percent debentures, due 2047.

The carrying amounts and fair values of long-term debt at June 30, 2017 and December 31, 2016 were:



(Millions of Dollars)	2017		2016
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$15,340	$17,052	$14,774	$16,093
CECONY	$12,570	$14,104	$12,073	$13,268


(a)	Amounts shown are net of unamortized debt expense and unamortized debt discount of $139 million and $116 million for Con Edison and CECONY, respectively, as of June 30, 2017 and $134 million and $113 million for Con Edison and CECONY, respectively, as of December 31, 2016.

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $16,416 million and $636 million of the fair value of long-term debt at June 30, 2017 are classified as Level 2 and Level 3, respectively. For CECONY, $13,468 million and $636 million of the fair value of long-term debt at June 30, 2017 are classified as Level 2 and Level 3, respectively (see Note L). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

Short-Term Borrowing	6 Months Ended
Short-Term Borrowing	Jun. 30, 2017
Debt Disclosure [Abstract]
Short-Term Borrowing	Short-Term Borrowing At June 30, 2017, Con Edison had $1,036 million of commercial paper outstanding of which $750 million was outstanding under CECONY’s program. The weighted average interest rate at June 30, 2017 was 1.3 percent for both Con Edison and CECONY. At December 31, 2016, Con Edison had $1,054 million of commercial paper outstanding of which $600 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2016 was 1.0 percent for both Con Edison and CECONY. At June 30, 2017 and December 31, 2016, no loans were outstanding under the credit agreement (Credit Agreement). An immaterial amount and $2 million (including $2 million for CECONY) of letters of credit were outstanding under the Credit Agreement as of June 30, 2017 and December 31, 2016, respectively.

Pension Benefits

6 Months Ended

Jun. 30, 2017

Retirement Benefits [Abstract]

Pension Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit costs for the three and six months ended June 30, 2017 and 2016 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Service cost – including administrative expenses	$66	$69	$61	$65
Interest cost on projected benefit obligation	148	149	139	140
Expected return on plan assets	(243)	(237)	(229)	(225)
Recognition of net actuarial loss	149	149	141	141
Recognition of prior service costs	(4)	1	(5)	—
TOTAL PERIODIC BENEFIT COST	$116	$131	$107	$121
Cost capitalized	(51)	(53)	(48)	(50)
Reconciliation to rate level	(3)	13	(5)	14
Cost charged to operating expenses	$62	$91	$54	$85



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Service cost – including administrative expenses	$132	$138	$123	$129
Interest cost on projected benefit obligation	296	298	277	280
Expected return on plan assets	(484)	(474)	(459)	(449)
Recognition of net actuarial loss	297	298	282	282
Recognition of prior service costs	(9)	2	(10)	1
NET PERIODIC BENEFIT COST	$232	$262	$213	$243
Cost capitalized	(94)	(106)	(88)	(99)
Reconciliation to rate level	(14)	26	(16)	26
Cost charged to operating expenses	$124	$182	$109	$170

Expected Contributions

Based on estimates as of June 30, 2017, the Companies expect to make contributions to the pension plans during 2017 of $450 million (of which $412 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 2017, the Companies contributed $283 million to the pension plans, nearly all of which was contributed by CECONY. CECONY also contributed $14 million to its external trust supplemental plans.

Other Postretirement Benefits

6 Months Ended

Jun. 30, 2017

Retirement Benefits [Abstract]

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, 2017 and 2016 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Service cost	$5	$4	$3	$3
Interest cost on accumulated other postretirement benefit obligation	11	12	10	10
Expected return on plan assets	(17)	(19)	(15)	(17)
Recognition of net actuarial loss/(gain)	1	1	(1)	1
Recognition of prior service cost	(4)	(5)	(3)	(3)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(4)	$(7)	$(6)	$(6)
Cost capitalized	2	2	3	2
Reconciliation to rate level	(1)	7	(1)	6
Cost charged to operating expenses	$(3)	$2	$(4)	$2



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Service cost	$10	$9	$7	$7
Interest cost on accumulated other postretirement benefit obligation	23	24	19	20
Expected return on plan assets	(35)	(38)	(30)	(34)
Recognition of net actuarial loss/(gain)	1	2	(2)	1
Recognition of prior service cost	(8)	(10)	(6)	(7)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(9)	$(13)	$(12)	$(13)
Cost capitalized	4	3	5	3
Reconciliation to rate level	(2)	14	(1)	14
Cost charged to operating expenses	$(7)	$4	$(8)	$4

Expected Contributions

Based on estimates as of June 30, 2017, Con Edison expects to make a contribution of $16 million, of which $8 million is to be contributed by CECONY, to the other postretirement benefit plans in 2017. The Companies' policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

Environmental Matters

6 Months Ended

Jun. 30, 2017

Environmental Remediation Obligations [Abstract]

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, 2017 and December 31, 2016 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Accrued Liabilities:
Manufactured gas plant sites	$659	$664	$565	$567
Other Superfund Sites	86	89	86	88
Total	$745	$753	$651	$655
Regulatory assets	$807	$823	$697	$711

Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) prudently incurred site investigation and remediation costs.

Environmental remediation costs incurred related to Superfund Sites for the three and six months ended June 30, 2017 and 2016 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Remediation costs incurred	$7	$9	$4	$3



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Remediation costs incurred	$14	$12	$11	$5

Insurance recoveries received by Con Edison or CECONY were immaterial for the three and six months ended June 30, 2017. No insurance recoveries were received by Con Edison or CECONY for the three or six months ended June 30, 2016.

In 2016, 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 $2.6 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, 2017, Con Edison and CECONY have accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. These estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Courts have begun, and unless otherwise determined on appeal may continue, to apply different standards for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims.

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at June 30, 2017 and December 31, 2016 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$89	$88	$85	$83
Regulatory assets – workers’ compensation	$14	$13	$14	$13

Other Material Contingencies

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

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 forty-five 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. In July 2017, the company reached agreements to resolve most of these suits which, after payment by the company of agreed-upon settlement amounts, are expected to be discontinued. 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, 2017, the company has accrued its estimated liability for the suits of $18 million and an insurance receivable of $18 million.

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 Streets in Manhattan were destroyed by an explosion and fire. CECONY had delivered gas to the buildings through service lines from a distribution main located below ground on Park Avenue. Eight people died and more than 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC. In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. In February 2017, the NYSPSC approved a settlement agreement with the company related to the NYSPSC's investigations of the incident and the practices of qualifying persons to perform plastic fusions. Pursuant to the agreement, the company will not recover from customers $126 million of costs it incurred for gas emergency response activities in 2014, 2015 and 2016 in excess of the amounts reflected in its gas rate plan and will provide $27 million of future benefits to customers (for which it has accrued a regulatory liability, see Note B). Approximately eighty suits are pending against the company seeking generally unspecified damages and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company 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, 2017, 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 $2,329 million and $2,370 million at June 30, 2017 and December 31, 2016, respectively.

A summary, by type and term, of Con Edison’s total guarantees at June 30, 2017 is as follows:



Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$643	$404		$—	$1,047
Energy transactions	497	31	215		743
Renewable electric production projects	392	—	19		411
Other	128	—	—		128
Total	$1,660	$435	$234		$2,329

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. In May 2016, the transmission owners transferred certain projects to NY Transco, for which CET Electric made its required contributions. NY Transco has proposed other transmission projects in the New York Independent System Operator's competitive bidding process. These other projects are 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 selection of the projects and resulting 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.

Energy Transactions — Con Edison guarantees payments on behalf of the Clean 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. Guarantee amounts shown above include $21 million of guarantees provided by Con Edison on behalf of Con Edison Solutions that may continue in effect during the period in which Con Edison Solutions provides transition services in connection with the retail electric supply business it sold in September 2016. As part of the sale agreement, the purchaser has agreed to pay Con Edison Solutions for draws on such guarantees.

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

Other — Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with operation of solar energy facilities and energy service projects of Con Edison Development and Con Edison Solutions, respectively. Other guarantees also includes Con Edison's guarantee (subject to a $53 million maximum amount) of certain obligations of Con Edison Solutions under the agreement pursuant to which it sold its retail electric supply business. 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. As part of the sale agreement for the retail electric supply business discussed above, the purchaser has agreed to pay Con Edison Solutions for draws on the guarantee to the Public Utility Commission of Texas.

Income Tax	6 Months Ended
Income Tax	Jun. 30, 2017
Income Tax Disclosure [Abstract]
Income Tax	Income Tax Con Edison’s income tax expense decreased to $102 million for the three months ended June 30, 2017 from $124 million for the three months ended June 30, 2016. Con Edison's effective tax rate for the three months ended June 30, 2017 and 2016 was 37 percent and 35 percent, respectively. The increase in Con Edison's effective tax rate is primarily due to a decrease in tax benefits for plant-related flow through items and higher reserves for injuries and damages, offset in part by lower state income taxes and bad debt expense. CECONY’s income tax expense increased to $91 million for the three months ended June 30, 2017 from $84 million for the three months ended June 30, 2016. CECONY's effective tax rate for the three months ended June 30, 2017 and 2016 was 39 percent and 34 percent, respectively. The increase in CECONY's effective tax rate is primarily due to a decrease in tax benefits for plant-related flow through items and higher reserves for injuries and damages, offset in part by lower state income taxes and bad debt expense. Con Edison’s income tax expense increased to $330 million for the six months ended June 30, 2017 from $288 million for the six months ended June 30, 2016. Con Edison's effective tax rate for the six months ended June 30, 2017 and 2016 was 37 percent and 35 percent, respectively. The increase in Con Edison's effective tax rate is primarily due to a decrease in tax benefits for plant-related flow through items and higher reserves for injuries and damages, offset in part by lower state income taxes and bad debt expense. CECONY’s income tax expense increased to $309 million for the six months ended June 30, 2017 from $264 million for the six months ended June 30, 2016. CECONY's effective tax rate for the six months ended June 30, 2017 and 2016 was 39 percent and 36 percent, respectively. The increase in CECONY's effective tax rate is primarily due to a decrease in tax benefits for plant-related flow through items, lower research and development tax credits and higher reserve for injuries and damages, offset in part by lower state income taxes and bad debt expense. Con Edison anticipates a federal consolidated net operating loss for 2017, primarily due to bonus depreciation. Con Edison expects to carryback a portion of its 2017 net operating loss to recover $18 million of income tax. The remaining 2017 net operating loss, as well as general business tax credits generated in 2017, 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, 2017, the estimated liability for uncertain tax positions for Con Edison was $40 million ($21 million for CECONY). Con Edison reasonably expects to resolve approximately $33 million ($23 million, net of federal taxes) of its uncertain tax positions within the next twelve months, including $19 million ($13 million, net of federal taxes), which, if recognized, would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $17 million ($12 million, net of federal taxes), including $2 million, which, if recognized, would reduce CECONY’s effective tax rate. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $23 million ($16 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, 2017, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At June 30, 2017 and December 31, 2016, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

Financial Information by Business Segment

6 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

Financial Information by Business Segment

Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. The financial data for the business segments for the three and six months ended June 30, 2017 and 2016 were as follows:



	For the Three Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2017	2016	2017		2016		2017	2016	2017	2016
CECONY
Electric	$1,817	$1,892	$4		$4		$229	$215	$330	$371
Gas	388	304	2		1		45	39	83	48
Steam	88	85	18		21		22	21	(26)	(27)
Consolidation adjustments	—	—	(24)		(26)		—	—	—	—
Total CECONY	$2,293	$2,281		$—		$—	$296	$275	$387	$392
O&R
Electric	$148	$144		$—		$—	$13	$13	$14	$14
Gas	47	31	—		—		4	4	5	(1)
Total O&R	$195	$175		$—		$—	$17	$17	$19	$13
Clean Energy Businesses	$146	$338		$—	$3		$18	$10	$18	$109
Con Edison Transmission	—	—	—		—		—	—	(2)	(1)
Other (a)	(1)	—	—		(3)		1	—	1	2
Total Con Edison	$2,633	$2,794		$—		$—	$332	$302	$423	$515



	For the Six Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2017	2016	2017		2016		2017	2016	2017	2016
CECONY
Electric	$3,610	$3,665	$8		$9		$458	$428	$622	$645
Gas	1,153	905	3		3		90	78	374	301
Steam	386	343	37		44		43	41	95	87
Consolidation adjustments	—	—	(48)		(56)		—	—	—	—
Total CECONY	$5,149	$4,913		$—		$—	$591	$547	$1,091	$1,033
O&R
Electric	$289	$284		$—		$—	$25	$24	$27	$32
Gas	144	106	—		—		10	9	44	34
Total O&R	$433	$390		$—		$—	$35	$33	$71	$66
Clean Energy Businesses	$283	$648		$—	$9		$36	$19	$34	$58
Con Edison Transmission	—	—	—		—		—	—	(4)	(1)
Other (a)	(4)	(1)	—		(9)		—	—	1	1
Total Con Edison	$5,861	$5,950		$—		$—	$662	$599	$1,193	$1,157

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

Derivative Instruments and Hedging Activities

6 Months Ended

Jun. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

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, 2017 and December 31, 2016 were:



(Millions of Dollars)	2017				2016
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	$93	$(78)	$15	(b)	$81	$(64)	$17	(b)
Noncurrent	63	(63)	—		49	(43)	6
Total fair value of derivative assets	$156	$(141)	$15		$130	$(107)	$23
Fair value of derivative liabilities
Current	$(153)	$89	$(64)		$(138)	$61	$(77)
Noncurrent	(136)	62	(74)		(91)	52	(39)	(c)
Total fair value of derivative liabilities	$(289)	$151	$(138)		$(229)	$113	$(116)
Net fair value derivative assets/(liabilities)	$(133)	$10	$(123)	(b)	$(99)	$6	$(93)	(b) (c)
CECONY
Fair value of derivative assets
Current	$52	$(48)	$4	(b)	$52	$(45)	$7	(b)
Noncurrent	53	(53)	—		41	(35)	6
Total fair value of derivative assets	$105	$(101)	$4		$93	$(80)	$13
Fair value of derivative liabilities
Current	$(105)	$56	$(49)		$(111)	$45	$(66)
Noncurrent	(119)	53	(66)		(77)	44	(33)
Total fair value of derivative liabilities	$(224)	$109	$(115)		$(188)	$89	$(99)
Net fair value derivative assets/(liabilities)	$(119)	$8	$(111)	(b)	$(95)	$9	$(86)	(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, 2017 and December 31, 2016, margin deposits for Con Edison ($7 million and $7 million, respectively) and CECONY ($7 million and $7 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)	Does not include $(1) million for interest rate swap.

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. The Clean 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, 2017 and 2016:



		For the Three Months Ended June 30,
		Con Edison					CECONY
(Millions of Dollars)	Balance Sheet Location	2017			2016		2017		2016
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(21)			$10		$(17)		$9
Noncurrent	Deferred derivative gains	—			1		—		—
Total deferred gains/(losses)		$(21)			$11		$(17)		$9
Current	Deferred derivative losses	$22			$68		$20		$61
Current	Recoverable energy costs	(40)			(52)		(39)		(47)
Noncurrent	Deferred derivative losses	(9)			68		(8)		62
Total deferred gains/(losses)		$(27)			$84		$(27)		$76
Net deferred gains/(losses)		$(48)			$95		$(44)		$85
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$—		$45	(b)		$—		$—
	Gas purchased for resale	(51)			(23)		—		—
	Non-utility revenue	(8)		(a)	5	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(59)			$27			$—		$—


(a)	For the three months ended June 30, 2017, Con Edison recorded an unrealized pre-tax loss in non-utility operating revenue ($7 million).


(b)	For the three months ended June 30, 2016, Con Edison recorded an unrealized pre-tax gain in purchased power expense ($97 million gain).



		For the Six Months Ended June 30,
		Con Edison					CECONY
(Millions of Dollars)	Balance Sheet Location	2017			2016		2017		2016
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(22)			$7		$(19)		$5
Noncurrent	Deferred derivative gains	(3)			1		(3)		(1)
Total deferred gains/(losses)		$(25)			$8		$(22)		$4
Current	Deferred derivative losses	$20			$38		$21		$33
Current	Recoverable energy costs	(85)			(125)		(78)		(113)
Noncurrent	Deferred derivative losses	(29)			12		(28)		11
Total deferred gains/(losses)		$(94)			$(75)		$(85)		$(69)
Net deferred gains/(losses)		$(119)			$(67)		$(107)		$(65)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$—		$(70)	(b)		$—		$—
	Gas purchased for resale	(114)			(33)		—		—
	Non-utility revenue	6		(a)	17	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(108)			$(86)			$—		$—


(a)	For the six months ended June 30, 2017, Con Edison recorded an unrealized pre-tax loss in non-utility operating revenue ($4 million).


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

The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at June 30, 2017:



	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	33,854,855	9,319	99,241,963	1,680,000
CECONY	31,442,175	4,500	91,970,000	1,680,000


(a)	Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported.


(b)	Excludes electric congestion and gas basis swap contracts, which are associated with electric and gas contracts and hedged volumes.

The Companies are exposed to credit risk related to transactions entered into primarily for the various energy supply and hedging activities by the Utilities and the Clean Energy Businesses. Credit risk relates to the loss that may result from a counterparty’s nonperformance. The Companies use credit policies to manage this risk, including an established credit approval process, monitoring of counterparty limits, netting provisions within agreements, collateral or prepayment arrangements, credit insurance and credit default swaps. The Companies measure credit risk exposure as the replacement cost for open energy commodity and derivative positions plus amounts owed from counterparties for settled transactions. The replacement cost of open positions represents unrealized gains, net of any unrealized losses where the Companies have a legally enforceable right to offset.

At June 30, 2017, Con Edison and CECONY had $70 million and $9 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $23 million with investment-grade counterparties, $21 million with non-investment grade/non-rated counterparties$13 million with commodity exchange brokers, and $13 million with independent system operators. CECONY’s net credit exposure consisted of $7 million with commodity exchange brokers and $2 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, 2017:



(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$128		$113
Collateral posted	41		41
Additional collateral (b) (downgrade one level from current ratings)	16		15
Additional collateral (b) (downgrade to below investment grade from current ratings)	99	(c)	84	(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 Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $12 million at June 30, 2017. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

(b)

The Companies measure the collateral requirements by taking into consideration the fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability position plus amounts owed to counterparties for settled transactions and amounts required by counterparties for minimum financial security. The fair value amounts represent unrealized losses, net of any unrealized gains where the Companies have a legally enforceable right to offset.


(c)	Derivative instruments that are net assets have been excluded from the table. At June 30, 2017, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $14 million.

Interest Rate Swap

In December 2016, the Clean Energy Businesses acquired Coram Wind project which holds an interest rate swap that terminates in June 2024, pursuant to which it pays a fixed-rate of 2.0855 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap was a liability of $1 million as of June 30, 2017 and December 31, 2016 on Con Edison’s consolidated balance sheet.

Fair Value Measurements

6 Months Ended

Jun. 30, 2017

Fair Value Disclosures [Abstract]

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, 2017 and December 31, 2016 are summarized below.



	2017					2016
(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)	$6	$37	$4	$(25)	$22	$14	$33	$7		$(24)	$30
Other (a)(b)(d)	264	116	—	—	380	222	111	—		—	333
Total assets	$270	$153	$4	$(25)	$402	$236	$144	$7		$(24)	$363
Derivative liabilities:
Commodity (a)(b)(c)	$3	$162	$14	$(42)	$137	$4	$144	$6		$(38)	$116
Interest Rate Swap (a)(b)(c)	—	1	—	—	1	—	1	—		—	1
Total liabilities	$3	$163	$14	$(42)	$138	$4	$145	$6		$(38)	$117
CECONY
Derivative assets:
Commodity (a)(b)(c)	$3	$5	$1	$2	$11	$10	$19	$1		$(10)	$20
Other (a)(b)(d)	241	111	—	—	352	200	106	—		—	306
Total assets	$244	$116	$1	$2	$363	$210	$125	$1		$(10)	$326
Derivative liabilities:
Commodity (a)(b)(c)	$1	$120	$7	$(13)	$115	$1	$124		$—	$(26)	$99


(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, 2017 and for the year ended December 31, 2016.

(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, 2017 and December 31, 2016, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.


(d)	Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans.


(e)	Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties.

The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives. Fair value and changes in fair value of commodity derivatives are reported on a monthly basis to the Companies’ risk committees, comprised of officers and employees of the Companies that oversee energy hedging at the Utilities and the Clean Energy Businesses. The risk management group reports to the Companies’ Vice President and Treasurer.



	Fair Value of Level 3 at June 30, 2017	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$(11)	Discounted Cash Flow	Forward energy prices (a)	$15.89-$79.00 per MWh
		Discounted Cash Flow	Forward capacity prices (a)	$2.42-$9.75 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
			Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.50-$9.30 per MWh
Total Con Edison—Commodity	$(10)
CECONY—Commodity
Electricity	$(7)	Discounted Cash Flow	Forward energy prices (a)	$22.50-$77.25 per MWh
Transmission Congestion Contracts	$1	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
Total CECONY—Commodity	$(6)


(a)	Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement.


(b)	Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement.

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, 2017 and 2016 and classified as Level 3 in the fair value hierarchy:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Beginning balance as of April 1,	$3	$(4)	$1	$2
Included in earnings	2	5	1	—
Included in regulatory assets and liabilities	(11)	1	(7)	(1)
Purchases	—	1	—	1
Settlements	(4)	2	(1)	—
Ending balance as of June 30,	$(10)	$5	$(6)	$2



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Beginning balance as of January 1,	$1	$6	$1	$8
Included in earnings	1	(2)	—	(1)
Included in regulatory assets and liabilities	(9)	(2)	(7)	(5)
Purchases	1	1	1	1
Settlements	(4)	2	(1)	(1)
Ending balance as of June 30,	$(10)	$5	$(6)	$2

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 Clean 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 ($1 million loss and $5 million gain) on the consolidated income statement for the three months ended June 30, 2017 and 2016, 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 ($1 million loss and $2 million loss) on the consolidated income statement for the six months ended June 30, 2017 and 2016, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at June 30, 2017 and 2016 is included in non-utility revenues (immaterial for both periods) and purchased power costs ($2 million loss and $7 million gain) on the consolidated income statement for the three months ended June 30, 2017 and 2016, respectively. For the six months ended June 30, 2017 and 2016, 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 ($2 million loss and $3 million gain) on the consolidated income statement, respectively.

Variable Interest Entities

6 Months Ended

Jun. 30, 2017

Equity Method Investments and Joint Ventures [Abstract]

Variable Interest Entities

Con Edison enters into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, Con Edison retains or may retain a variable interest in these entities.

CECONY has an ongoing long-term electricity purchase agreement with Brooklyn Navy Yard Cogeneration Partners, LP, a potential variable interest entity (VIE). In April 2017, CECONY's long-term electricity purchase agreement with Cogen Technologies Linden Venture, LP, another potential VIE, expired. In 2016, requests were made of these 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, 2017:



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	$176
Mesquite Solar 1	83	20	2013	Arizona	102
Copper Mountain Solar 2	75	25	2013	Nevada	83
California Solar	55	25	2012	California	62
Broken Bow II	38	25	2014	Nebraska	46
Texas Solar 4	32	25	2014	Texas	47

(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. With the exception of Texas Solar 4, Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development.

(b) 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. For consolidated investments, such as Texas Solar 4, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest ($7 million for Texas Solar 4). Con Edison did not provide any financial or other support during the three and six months ended June 30, 2017 that was not previously contractually required.

New Financial Accounting Standards	6 Months Ended
New Financial Accounting Standards	Jun. 30, 2017
Accounting Changes and Error Corrections [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. Amendments were issued subsequently to clarify key areas including principal/agent considerations, performance obligations, licensing, sales taxes, noncash consideration, and contracts. 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, however, the Companies plan to adopt the new standard for reporting periods beginning after December 15, 2017. Under the new standard, companies may use either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a modified retrospective approach with the cumulative effect of initially adopting ASU 2014-09 recognized at the date of adoption (which includes additional footnote disclosures). The Companies anticipate using the modified retrospective approach. The Companies are currently in the process of evaluating the impact of the new standard on their various revenue streams. The majority of the Companies’ sales are derived from tariffs to provide electric, gas, and steam service to customers. For such tariffs, the Companies expect that the revenue from contracts with the customer under ASU 2014-09 will be equivalent to the electricity, gas, or steam supplied in that period which is consistent with current practice. Consequently, the Companies do not anticipate that the new standard will materially impact the amount and/or timing of such revenues. The Companies continue to review the potential impacts of other revenue at the Utilities and the Clean Energy Businesses on the Companies' financial position, results of operations and liquidity as well as the additional disclosures required under the new standard. 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. Based on the existing portfolio of leases at implementation, for leases currently classified as operating leases, the Companies expect to recognize on the statements of financial position right-of-use assets and lease liabilities. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ results of operations and liquidity. In January 2017, the FASB issued amendments to the guidance for Business Combinations through ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business.” The amendments in this update clarify the definition of a business and provide guidance on evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. 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 January 2017, the FASB issued amendments to the guidance for the subsequent measurement of goodwill through ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The amendments in this update simplify goodwill impairment testing by eliminating Step 2 of the goodwill impairment test wherein an entity has to compute the implied fair value of goodwill by performing procedures to determine the fair value of its assets and liabilities. Under the new guidance, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value up to the total amount of goodwill allocated to that reporting unit. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. 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 February 2017, the FASB issued amendments to the guidance for other income through ASU 2017-05, “Other Income-Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets.” The amendments in this update clarify the scope of assets within Subtopic 610-20 and add guidance for partial sales of nonfinancial assets. The amendments are effective upon the adoption of ASU 2014-09, and therefore will be effective for reporting periods beginning after December 15, 2017. The Company is in the process of evaluating the potential impact of the new guidance on the Company’s financial position, results of operations and liquidity. In March 2017, the FASB issued amendments to the guidance for retirement benefits through ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The amendments in this update modify the presentation of net benefit cost, where the service component must be disaggregated from the other components of net benefit cost and be presented in the same line item as current employee compensation costs. The remaining components of the net benefit cost should be presented outside of income from operations. Additionally, the update allows only the service cost component to be eligible for capitalization. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. 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 2017, the FASB issued amendments to the guidance for debt securities through ASU 2017-08, “Receivables-Nonrefundable Fees and Other Costs (Subtopic 310-20): Premium Amortization on Purchased Callable Debt Securities.” The amendments in this update shorten the amortization period for certain callable debt securities held at a premium. The amendments do not require an accounting change for securities held at a discount; the discount continues to be amortized to maturity. For public entities, the amendments are effective for reporting periods beginning after December 15, 2018. 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 2017, the FASB issued amendments to the guidance for stock compensation through ASU 2017-09, “Compensation-Stock Compensation (Topic 718): Scope of Modification Accounting.” The amendments in this update specify that changes to value, vesting conditions, or classification of an existing share-based payment award require application of modification accounting in Topic 718. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. 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.

Dispositions	6 Months Ended
Dispositions	Jun. 30, 2017
Discontinued Operations and Disposal Groups [Abstract]
Dispositions	Dispositions Upton 2 In May 2017, Con Edison Development sold Upton 2, a development stage solar electric production project, for $11 million to Vistra Asset Co. and recorded a $1 million gain on sale ($0.7 million, net of taxes). In addition, Con Edison Development agreed to perform the engineering, procurement and construction for the 180 MW (AC) project, which is expected to be substantially completed in 2018.

New Financial Accounting Standards (Policies)	6 Months Ended
New Financial Accounting Standards (Policies)	Jun. 30, 2017
Accounting Changes and Error Corrections [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. Amendments were issued subsequently to clarify key areas including principal/agent considerations, performance obligations, licensing, sales taxes, noncash consideration, and contracts. 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, however, the Companies plan to adopt the new standard for reporting periods beginning after December 15, 2017. Under the new standard, companies may use either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a modified retrospective approach with the cumulative effect of initially adopting ASU 2014-09 recognized at the date of adoption (which includes additional footnote disclosures). The Companies anticipate using the modified retrospective approach. The Companies are currently in the process of evaluating the impact of the new standard on their various revenue streams. The majority of the Companies’ sales are derived from tariffs to provide electric, gas, and steam service to customers. For such tariffs, the Companies expect that the revenue from contracts with the customer under ASU 2014-09 will be equivalent to the electricity, gas, or steam supplied in that period which is consistent with current practice. Consequently, the Companies do not anticipate that the new standard will materially impact the amount and/or timing of such revenues. The Companies continue to review the potential impacts of other revenue at the Utilities and the Clean Energy Businesses on the Companies' financial position, results of operations and liquidity as well as the additional disclosures required under the new standard. 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. Based on the existing portfolio of leases at implementation, for leases currently classified as operating leases, the Companies expect to recognize on the statements of financial position right-of-use assets and lease liabilities. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ results of operations and liquidity. In January 2017, the FASB issued amendments to the guidance for Business Combinations through ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business.” The amendments in this update clarify the definition of a business and provide guidance on evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. 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 January 2017, the FASB issued amendments to the guidance for the subsequent measurement of goodwill through ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The amendments in this update simplify goodwill impairment testing by eliminating Step 2 of the goodwill impairment test wherein an entity has to compute the implied fair value of goodwill by performing procedures to determine the fair value of its assets and liabilities. Under the new guidance, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value up to the total amount of goodwill allocated to that reporting unit. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. 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 February 2017, the FASB issued amendments to the guidance for other income through ASU 2017-05, “Other Income-Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets.” The amendments in this update clarify the scope of assets within Subtopic 610-20 and add guidance for partial sales of nonfinancial assets. The amendments are effective upon the adoption of ASU 2014-09, and therefore will be effective for reporting periods beginning after December 15, 2017. The Company is in the process of evaluating the potential impact of the new guidance on the Company’s financial position, results of operations and liquidity. In March 2017, the FASB issued amendments to the guidance for retirement benefits through ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The amendments in this update modify the presentation of net benefit cost, where the service component must be disaggregated from the other components of net benefit cost and be presented in the same line item as current employee compensation costs. The remaining components of the net benefit cost should be presented outside of income from operations. Additionally, the update allows only the service cost component to be eligible for capitalization. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. 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 2017, the FASB issued amendments to the guidance for debt securities through ASU 2017-08, “Receivables-Nonrefundable Fees and Other Costs (Subtopic 310-20): Premium Amortization on Purchased Callable Debt Securities.” The amendments in this update shorten the amortization period for certain callable debt securities held at a premium. The amendments do not require an accounting change for securities held at a discount; the discount continues to be amortized to maturity. For public entities, the amendments are effective for reporting periods beginning after December 15, 2018. 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 2017, the FASB issued amendments to the guidance for stock compensation through ASU 2017-09, “Compensation-Stock Compensation (Topic 718): Scope of Modification Accounting.” The amendments in this update specify that changes to value, vesting conditions, or classification of an existing share-based payment award require application of modification accounting in Topic 718. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2017

Accounting Policies [Abstract]

Basic and Diluted Earnings Per Share

For the three and six months ended June 30, 2017 and 2016, basic and diluted 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)	2017	2016	2017	2016
Net income	$175	$232	$563	$542
Weighted average common shares outstanding – basic	305.4	299.1	305.3	296.7
Add: Incremental shares attributable to effect of potentially dilutive securities	1.4	1.3	1.4	1.3
Adjusted weighted average common shares outstanding – diluted	306.8	300.4	306.7	298.0
Net Income per common share – basic	$0.57	$0.78	$1.84	$1.83
Net Income per common share – diluted	$0.57	$0.77	$1.84	$1.82

Changes in Accumulated Other Comprehensive Income/(Loss)

For the three and six months ended June 30, 2017 and 2016, 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)	2017	2016	2017	2016
Beginning balance, accumulated OCI, net of taxes (a)	$(28)	$(34)	$(7)	$(9)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2017 and 2016 (a)(b)	1	1	—	1
Current period OCI, net of taxes	1	1	—	1
Ending balance, accumulated OCI, net of taxes	$(27)	$(33)	$(7)	$(8)



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Beginning balance, accumulated OCI, net of taxes (a)	$(27)	$(34)	$(7)	$(9)
OCI before reclassifications, net of tax of $1 for Con Edison in 2017 and 2016	(2)	(1)	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2017 and 2016 (a)(b)	2	2	—	1
Current period OCI, net of taxes	—	1	—	1
Ending balance, accumulated OCI, net of taxes	$(27)	$(33)	$(7)	$(8)


(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, 2017

Regulated Operations [Abstract]

Summary of Utilities Rate Plans

The following table contains a summary of the electric rate plan.



RECO
Effective period		March 2017 (a)
Base rate changes		Yr. 1 - $1.7 million
Amortization to income of net regulatory (assets) and liabilities		$0.2 million over three years and continuation of $(25.6) million of deferred storm costs over four years expiring July 31, 2018 (b)
Recoverable energy costs		Current rate recovery of purchased power costs.
Cost reconciliations		None
Average rate base		Yr. 1 - $178.7 million
Weighted average cost of capital (after-tax)		7.47 percent
Authorized return on common equity		9.6 percent
Cost of long-term debt		5.37 percent
Common equity ratio		49.7 percent


(a)	Effective until a new rate plan approved by the NJBPU goes into effect.


(b)	In January 2016, the NJBPU approved RECO’s plan to spend $15.7 million in capital over three years to harden its electric system against storms, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge.

Schedule of Regulatory Assets

Regulatory assets and liabilities at June 30, 2017 and December 31, 2016 were comprised of the following items:



	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Regulatory assets
Unrecognized pension and other postretirement costs	$2,768	$2,874	$2,612	$2,730
Future income tax	2,413	2,439	2,302	2,325
Environmental remediation costs	807	823	697	711
Revenue taxes	327	295	311	280
Deferred derivative losses	77	48	70	42
Pension and other postretirement benefits deferrals	59	38	32	7
Municipal infrastructure support costs	54	44	54	44
Deferred storm costs	44	56	—	3
Unamortized loss on reacquired debt	40	43	38	41
Indian Point Energy Center program costs	40	50	40	50
Surcharge for New York State assessment	32	28	30	26
O&R property tax reconciliation	32	37	—	—
Brooklyn Queens demand management program	26	29	26	29
Preferred stock redemption	25	25	25	25
Net electric deferrals	17	24	17	24
Recoverable energy costs	15	42	15	38
Workers’ compensation	14	13	14	13
O&R transition bond charges	12	15	—	—
Other	133	101	121	85
Regulatory assets – noncurrent	6,935	7,024	6,404	6,473
Deferred derivative losses	71	91	65	86
Recoverable energy costs	6	9	3	4
Regulatory assets – current	77	100	68	90
Total Regulatory Assets	$7,012	$7,124	$6,472	$6,563
Regulatory liabilities
Allowance for cost of removal less salvage	$786	$755	$661	$641
Pension and other postretirement benefit deferrals	206	193	177	162
Net unbilled revenue deferrals	164	145	164	145
Property tax reconciliation	148	178	148	178
Unrecognized other postretirement costs	88	60	88	60
Settlement of prudence proceeding	80	95	80	95
Carrying charges on repair allowance and bonus depreciation	55	68	54	67
New York State income tax rate change	53	61	52	60
Variable-rate tax-exempt debt – cost rate reconciliation	43	55	38	48
Base rate change deferrals	31	40	31	40
Settlement of gas proceedings	27	27	27	27
Earnings sharing - electric, gas and steam	22	39	13	28
Net utility plant reconciliations	12	16	10	15
Other	171	173	143	146
Regulatory liabilities – noncurrent	1,886	1,905	1,686	1,712
Refundable energy costs	29	29	10	5
Revenue decoupling mechanism	29	71	27	61
Deferred derivative gains	6	28	5	24
Regulatory liabilities – current	64	128	42	90
Total Regulatory Liabilities	$1,950	$2,033	$1,728	$1,802

Schedule of Regulatory Liabilities

Regulatory assets and liabilities at June 30, 2017 and December 31, 2016 were comprised of the following items:



	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Regulatory assets
Unrecognized pension and other postretirement costs	$2,768	$2,874	$2,612	$2,730
Future income tax	2,413	2,439	2,302	2,325
Environmental remediation costs	807	823	697	711
Revenue taxes	327	295	311	280
Deferred derivative losses	77	48	70	42
Pension and other postretirement benefits deferrals	59	38	32	7
Municipal infrastructure support costs	54	44	54	44
Deferred storm costs	44	56	—	3
Unamortized loss on reacquired debt	40	43	38	41
Indian Point Energy Center program costs	40	50	40	50
Surcharge for New York State assessment	32	28	30	26
O&R property tax reconciliation	32	37	—	—
Brooklyn Queens demand management program	26	29	26	29
Preferred stock redemption	25	25	25	25
Net electric deferrals	17	24	17	24
Recoverable energy costs	15	42	15	38
Workers’ compensation	14	13	14	13
O&R transition bond charges	12	15	—	—
Other	133	101	121	85
Regulatory assets – noncurrent	6,935	7,024	6,404	6,473
Deferred derivative losses	71	91	65	86
Recoverable energy costs	6	9	3	4
Regulatory assets – current	77	100	68	90
Total Regulatory Assets	$7,012	$7,124	$6,472	$6,563
Regulatory liabilities
Allowance for cost of removal less salvage	$786	$755	$661	$641
Pension and other postretirement benefit deferrals	206	193	177	162
Net unbilled revenue deferrals	164	145	164	145
Property tax reconciliation	148	178	148	178
Unrecognized other postretirement costs	88	60	88	60
Settlement of prudence proceeding	80	95	80	95
Carrying charges on repair allowance and bonus depreciation	55	68	54	67
New York State income tax rate change	53	61	52	60
Variable-rate tax-exempt debt – cost rate reconciliation	43	55	38	48
Base rate change deferrals	31	40	31	40
Settlement of gas proceedings	27	27	27	27
Earnings sharing - electric, gas and steam	22	39	13	28
Net utility plant reconciliations	12	16	10	15
Other	171	173	143	146
Regulatory liabilities – noncurrent	1,886	1,905	1,686	1,712
Refundable energy costs	29	29	10	5
Revenue decoupling mechanism	29	71	27	61
Deferred derivative gains	6	28	5	24
Regulatory liabilities – current	64	128	42	90
Total Regulatory Liabilities	$1,950	$2,033	$1,728	$1,802

Capitalization (Tables)

6 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

Carrying Amounts and Fair Values of Long-Term Debt

The carrying amounts and fair values of long-term debt at June 30, 2017 and December 31, 2016 were:



(Millions of Dollars)	2017		2016
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$15,340	$17,052	$14,774	$16,093
CECONY	$12,570	$14,104	$12,073	$13,268


(a)	Amounts shown are net of unamortized debt expense and unamortized debt discount of $139 million and $116 million for Con Edison and CECONY, respectively, as of June 30, 2017 and $134 million and $113 million for Con Edison and CECONY, respectively, as of December 31, 2016.

Pension Benefits (Tables)

6 Months Ended

Jun. 30, 2017

Pension Benefits

Total Periodic Benefit Costs

The components of the Companies’ total periodic benefit costs for the three and six months ended June 30, 2017 and 2016 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Service cost – including administrative expenses	$66	$69	$61	$65
Interest cost on projected benefit obligation	148	149	139	140
Expected return on plan assets	(243)	(237)	(229)	(225)
Recognition of net actuarial loss	149	149	141	141
Recognition of prior service costs	(4)	1	(5)	—
TOTAL PERIODIC BENEFIT COST	$116	$131	$107	$121
Cost capitalized	(51)	(53)	(48)	(50)
Reconciliation to rate level	(3)	13	(5)	14
Cost charged to operating expenses	$62	$91	$54	$85



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Service cost – including administrative expenses	$132	$138	$123	$129
Interest cost on projected benefit obligation	296	298	277	280
Expected return on plan assets	(484)	(474)	(459)	(449)
Recognition of net actuarial loss	297	298	282	282
Recognition of prior service costs	(9)	2	(10)	1
NET PERIODIC BENEFIT COST	$232	$262	$213	$243
Cost capitalized	(94)	(106)	(88)	(99)
Reconciliation to rate level	(14)	26	(16)	26
Cost charged to operating expenses	$124	$182	$109	$170

Other Postretirement Benefits (Tables)

6 Months Ended

Jun. 30, 2017

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, 2017 and 2016 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Service cost	$5	$4	$3	$3
Interest cost on accumulated other postretirement benefit obligation	11	12	10	10
Expected return on plan assets	(17)	(19)	(15)	(17)
Recognition of net actuarial loss/(gain)	1	1	(1)	1
Recognition of prior service cost	(4)	(5)	(3)	(3)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(4)	$(7)	$(6)	$(6)
Cost capitalized	2	2	3	2
Reconciliation to rate level	(1)	7	(1)	6
Cost charged to operating expenses	$(3)	$2	$(4)	$2



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Service cost	$10	$9	$7	$7
Interest cost on accumulated other postretirement benefit obligation	23	24	19	20
Expected return on plan assets	(35)	(38)	(30)	(34)
Recognition of net actuarial loss/(gain)	1	2	(2)	1
Recognition of prior service cost	(8)	(10)	(6)	(7)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(9)	$(13)	$(12)	$(13)
Cost capitalized	4	3	5	3
Reconciliation to rate level	(2)	14	(1)	14
Cost charged to operating expenses	$(7)	$4	$(8)	$4

Environmental Matters (Tables)

6 Months Ended

Jun. 30, 2017

Environmental Remediation Obligations [Abstract]

Accrued Liabilities and Regulatory Assets

The accrued liabilities and regulatory assets related to Superfund Sites at June 30, 2017 and December 31, 2016 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Accrued Liabilities:
Manufactured gas plant sites	$659	$664	$565	$567
Other Superfund Sites	86	89	86	88
Total	$745	$753	$651	$655
Regulatory assets	$807	$823	$697	$711

Environmental Remediation Costs

Environmental remediation costs incurred related to Superfund Sites for the three and six months ended June 30, 2017 and 2016 were as follows:



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Remediation costs incurred	$7	$9	$4	$3



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Remediation costs incurred	$14	$12	$11	$5

Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings



	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$89	$88	$85	$83
Regulatory assets – workers’ compensation	$14	$13	$14	$13

Other Material Contingencies (Tables)

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Summary of Total Guarantees

A summary, by type and term, of Con Edison’s total guarantees at June 30, 2017 is as follows:



Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$643	$404		$—	$1,047
Energy transactions	497	31	215		743
Renewable electric production projects	392	—	19		411
Other	128	—	—		128
Total	$1,660	$435	$234		$2,329

Financial Information by Business Segment (Tables)

6 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

Financial Data for Business Segments

The financial data for the business segments for the three and six months ended June 30, 2017 and 2016 were as follows:



	For the Three Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2017	2016	2017		2016		2017	2016	2017	2016
CECONY
Electric	$1,817	$1,892	$4		$4		$229	$215	$330	$371
Gas	388	304	2		1		45	39	83	48
Steam	88	85	18		21		22	21	(26)	(27)
Consolidation adjustments	—	—	(24)		(26)		—	—	—	—
Total CECONY	$2,293	$2,281		$—		$—	$296	$275	$387	$392
O&R
Electric	$148	$144		$—		$—	$13	$13	$14	$14
Gas	47	31	—		—		4	4	5	(1)
Total O&R	$195	$175		$—		$—	$17	$17	$19	$13
Clean Energy Businesses	$146	$338		$—	$3		$18	$10	$18	$109
Con Edison Transmission	—	—	—		—		—	—	(2)	(1)
Other (a)	(1)	—	—		(3)		1	—	1	2
Total Con Edison	$2,633	$2,794		$—		$—	$332	$302	$423	$515



	For the Six Months Ended June 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2017	2016	2017		2016		2017	2016	2017	2016
CECONY
Electric	$3,610	$3,665	$8		$9		$458	$428	$622	$645
Gas	1,153	905	3		3		90	78	374	301
Steam	386	343	37		44		43	41	95	87
Consolidation adjustments	—	—	(48)		(56)		—	—	—	—
Total CECONY	$5,149	$4,913		$—		$—	$591	$547	$1,091	$1,033
O&R
Electric	$289	$284		$—		$—	$25	$24	$27	$32
Gas	144	106	—		—		10	9	44	34
Total O&R	$433	$390		$—		$—	$35	$33	$71	$66
Clean Energy Businesses	$283	$648		$—	$9		$36	$19	$34	$58
Con Edison Transmission	—	—	—		—		—	—	(4)	(1)
Other (a)	(4)	(1)	—		(9)		—	—	1	1
Total Con Edison	$5,861	$5,950		$—		$—	$662	$599	$1,193	$1,157

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

Derivative Instruments and Hedging Activities (Tables)

6 Months Ended

Jun. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Offsetting of Liabilities

The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at June 30, 2017 and December 31, 2016 were:



(Millions of Dollars)	2017				2016
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	$93	$(78)	$15	(b)	$81	$(64)	$17	(b)
Noncurrent	63	(63)	—		49	(43)	6
Total fair value of derivative assets	$156	$(141)	$15		$130	$(107)	$23
Fair value of derivative liabilities
Current	$(153)	$89	$(64)		$(138)	$61	$(77)
Noncurrent	(136)	62	(74)		(91)	52	(39)	(c)
Total fair value of derivative liabilities	$(289)	$151	$(138)		$(229)	$113	$(116)
Net fair value derivative assets/(liabilities)	$(133)	$10	$(123)	(b)	$(99)	$6	$(93)	(b) (c)
CECONY
Fair value of derivative assets
Current	$52	$(48)	$4	(b)	$52	$(45)	$7	(b)
Noncurrent	53	(53)	—		41	(35)	6
Total fair value of derivative assets	$105	$(101)	$4		$93	$(80)	$13
Fair value of derivative liabilities
Current	$(105)	$56	$(49)		$(111)	$45	$(66)
Noncurrent	(119)	53	(66)		(77)	44	(33)
Total fair value of derivative liabilities	$(224)	$109	$(115)		$(188)	$89	$(99)
Net fair value derivative assets/(liabilities)	$(119)	$8	$(111)	(b)	$(95)	$9	$(86)	(b)

(a)

(b)


(c)	Does not include $(1) million for interest rate swap.

Offsetting of Assets

The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at June 30, 2017 and December 31, 2016 were:



(Millions of Dollars)	2017				2016
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	$93	$(78)	$15	(b)	$81	$(64)	$17	(b)
Noncurrent	63	(63)	—		49	(43)	6
Total fair value of derivative assets	$156	$(141)	$15		$130	$(107)	$23
Fair value of derivative liabilities
Current	$(153)	$89	$(64)		$(138)	$61	$(77)
Noncurrent	(136)	62	(74)		(91)	52	(39)	(c)
Total fair value of derivative liabilities	$(289)	$151	$(138)		$(229)	$113	$(116)
Net fair value derivative assets/(liabilities)	$(133)	$10	$(123)	(b)	$(99)	$6	$(93)	(b) (c)
CECONY
Fair value of derivative assets
Current	$52	$(48)	$4	(b)	$52	$(45)	$7	(b)
Noncurrent	53	(53)	—		41	(35)	6
Total fair value of derivative assets	$105	$(101)	$4		$93	$(80)	$13
Fair value of derivative liabilities
Current	$(105)	$56	$(49)		$(111)	$45	$(66)
Noncurrent	(119)	53	(66)		(77)	44	(33)
Total fair value of derivative liabilities	$(224)	$109	$(115)		$(188)	$89	$(99)
Net fair value derivative assets/(liabilities)	$(119)	$8	$(111)	(b)	$(95)	$9	$(86)	(b)

(a)

(b)


(c)	Does not include $(1) million for interest rate swap.

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	2017			2016		2017		2016
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(21)			$10		$(17)		$9
Noncurrent	Deferred derivative gains	—			1		—		—
Total deferred gains/(losses)		$(21)			$11		$(17)		$9
Current	Deferred derivative losses	$22			$68		$20		$61
Current	Recoverable energy costs	(40)			(52)		(39)		(47)
Noncurrent	Deferred derivative losses	(9)			68		(8)		62
Total deferred gains/(losses)		$(27)			$84		$(27)		$76
Net deferred gains/(losses)		$(48)			$95		$(44)		$85
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$—		$45	(b)		$—		$—
	Gas purchased for resale	(51)			(23)		—		—
	Non-utility revenue	(8)		(a)	5	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(59)			$27			$—		$—


(a)	For the three months ended June 30, 2017, Con Edison recorded an unrealized pre-tax loss in non-utility operating revenue ($7 million).


(b)	For the three months ended June 30, 2016, Con Edison recorded an unrealized pre-tax gain in purchased power expense ($97 million gain).



		For the Six Months Ended June 30,
		Con Edison					CECONY
(Millions of Dollars)	Balance Sheet Location	2017			2016		2017		2016
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(22)			$7		$(19)		$5
Noncurrent	Deferred derivative gains	(3)			1		(3)		(1)
Total deferred gains/(losses)		$(25)			$8		$(22)		$4
Current	Deferred derivative losses	$20			$38		$21		$33
Current	Recoverable energy costs	(85)			(125)		(78)		(113)
Noncurrent	Deferred derivative losses	(29)			12		(28)		11
Total deferred gains/(losses)		$(94)			$(75)		$(85)		$(69)
Net deferred gains/(losses)		$(119)			$(67)		$(107)		$(65)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$—		$(70)	(b)		$—		$—
	Gas purchased for resale	(114)			(33)		—		—
	Non-utility revenue	6		(a)	17	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(108)			$(86)			$—		$—


(a)	For the six months ended June 30, 2017, Con Edison recorded an unrealized pre-tax loss in non-utility operating revenue ($4 million).


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

Hedged Volume of Derivative Transactions

The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at June 30, 2017:



	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	33,854,855	9,319	99,241,963	1,680,000
CECONY	31,442,175	4,500	91,970,000	1,680,000


(a)	Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported.


(b)	Excludes electric congestion and gas basis swap contracts, which are associated with electric and gas contracts and hedged volumes.

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



(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$128		$113
Collateral posted	41		41
Additional collateral (b) (downgrade one level from current ratings)	16		15
Additional collateral (b) (downgrade to below investment grade from current ratings)	99	(c)	84	(c)

(a)

(b)


(c)	Derivative instruments that are net assets have been excluded from the table. At June 30, 2017, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $14 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
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=84234895&loc=d3e41641-113959

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=84234895&loc=SL5624163-113959

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=84234895&loc=d3e41678-113959

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=84234895&loc=d3e41638-113959

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=84234895&loc=SL5580258-113959

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=84234895&loc=SL5579245-113959

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=84234895&loc=SL5624171-113959

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=84234895&loc=SL5579240-113959

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=84234895&loc=d3e41620-113959

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(n)(2))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

+ Details

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2017

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, 2017 and December 31, 2016 are summarized below.



	2017					2016
(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)	$6	$37	$4	$(25)	$22	$14	$33	$7		$(24)	$30
Other (a)(b)(d)	264	116	—	—	380	222	111	—		—	333
Total assets	$270	$153	$4	$(25)	$402	$236	$144	$7		$(24)	$363
Derivative liabilities:
Commodity (a)(b)(c)	$3	$162	$14	$(42)	$137	$4	$144	$6		$(38)	$116
Interest Rate Swap (a)(b)(c)	—	1	—	—	1	—	1	—		—	1
Total liabilities	$3	$163	$14	$(42)	$138	$4	$145	$6		$(38)	$117
CECONY
Derivative assets:
Commodity (a)(b)(c)	$3	$5	$1	$2	$11	$10	$19	$1		$(10)	$20
Other (a)(b)(d)	241	111	—	—	352	200	106	—		—	306
Total assets	$244	$116	$1	$2	$363	$210	$125	$1		$(10)	$326
Derivative liabilities:
Commodity (a)(b)(c)	$1	$120	$7	$(13)	$115	$1	$124		$—	$(26)	$99


(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, 2017 and for the year ended December 31, 2016.

(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.

Schedule of Commodity Derivatives



	Fair Value of Level 3 at June 30, 2017	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$(11)	Discounted Cash Flow	Forward energy prices (a)	$15.89-$79.00 per MWh
		Discounted Cash Flow	Forward capacity prices (a)	$2.42-$9.75 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
			Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.50-$9.30 per MWh
Total Con Edison—Commodity	$(10)
CECONY—Commodity
Electricity	$(7)	Discounted Cash Flow	Forward energy prices (a)	$22.50-$77.25 per MWh
Transmission Congestion Contracts	$1	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
Total CECONY—Commodity	$(6)


(a)	Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement.


(b)	Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement.

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)	2017	2016	2017	2016
Beginning balance as of April 1,	$3	$(4)	$1	$2
Included in earnings	2	5	1	—
Included in regulatory assets and liabilities	(11)	1	(7)	(1)
Purchases	—	1	—	1
Settlements	(4)	2	(1)	—
Ending balance as of June 30,	$(10)	$5	$(6)	$2



	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Beginning balance as of January 1,	$1	$6	$1	$8
Included in earnings	1	(2)	—	(1)
Included in regulatory assets and liabilities	(9)	(2)	(7)	(5)
Purchases	1	1	1	1
Settlements	(4)	2	(1)	(1)
Ending balance as of June 30,	$(10)	$5	$(6)	$2

Variable Interest Entities (Tables)

6 Months Ended

Jun. 30, 2017

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, 2017:



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	$176
Mesquite Solar 1	83	20	2013	Arizona	102
Copper Mountain Solar 2	75	25	2013	Nevada	83
California Solar	55	25	2012	California	62
Broken Bow II	38	25	2014	Nebraska	46
Texas Solar 4	32	25	2014	Texas	47

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

- 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

General (Details)	6 Months Ended
General (Details)	Jun. 30, 2017 subsidiary registrant
Accounting Policies [Abstract]
Number of registrants \| registrant	2
Number of regulated utility subsidiaries	2
Clean Energy Businesses
Investment [Line Items]
Number of subsidiaries	3

Summary of Significant Accounting Policies - Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2016	Mar. 31, 2016	Jun. 30, 2017	Jun. 30, 2016
Accounting Policies [Abstract]
Net income	$ 175	$ 388	$ 232	$ 310	$ 563	$ 542
Weighted average common shares outstanding – basic	305.4		299.1		305.3	296.7
Add: Incremental shares attributable to effect of potentially dilutive securities	1.4		1.3		1.4	1.3
Adjusted weighted average common shares outstanding – diluted	306.8		300.4		306.7	298.0
Net income per common share-basic (dollars per share)	$ 0.57		$ 0.78		$ 1.84	$ 1.83
Net income per common share-diluted (dollars per share)	$ 0.57		$ 0.77		$ 1.84	$ 1.82

Summary of Significant Accounting Policies - Changes in Accumulated Other Comprehensive Income/(Loss) by Component (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2016	Mar. 31, 2016	Jun. 30, 2017	Jun. 30, 2016
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	$ 14,506	$ 14,306	$ 13,201	$ 13,061	$ 14,306	$ 13,061
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	(1)	1	0	0	1
Ending Balance	14,498	14,506	13,958	13,201	14,498	13,958
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(28)	(27)	(34)	(34)	(27)	(34)
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	(1)	1
Ending Balance	(27)	(28)	(33)	(34)	(27)	(33)
Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax of $1 for Con Edison in 2017 and 2016					(2)	(1)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	1		1		2	2
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1		1		0	1
OCI before reclassifications, tax					1	1
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]
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	0	0	1	0	0	1
CECONY \| Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(7)	(7)	(9)	(9)	(7)	(9)
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES			1	0
Ending Balance	(7)	$ (7)	(8)	$ (9)	(7)	(8)
CECONY \| Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax of $1 for Con Edison in 2017 and 2016					0	0
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	0		1		0	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	$ 0		$ 1		$ 0	$ 1

Regulatory Matters - Summary of Utilities Rate Plans (Details) - Rockland Electric Company (RECO) - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	Jan. 31, 2016	Jun. 30, 2017
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 1.7
Amortization to income of net regulatory liabilities		$ 0.2
Regulatory liabilities, amortization period		3 years
Amortization to income of net regulatory assets		$ (25.6)
Regulatory assets, amortization period		4 years
Average rate base		$ 178.7
Weighted average cost of capital (after-tax) (percent)		7.47%
Authorized return on common equity (percent)		9.60%
Cost of long-term debt (percent)		5.37%
Common equity ratio (percent)		49.70%
Electric
Public Utilities, General Disclosures [Line Items]
Plan electric system storm hardening amount	$ 15.7
Plan period (years)	3 years

Regulatory Matters - Additional Information (Details) - FERC - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2017	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Requested return on equity (percent)	10.70%
Requested equity capital structure (percent)	48.00%
RECO
Public Utilities, General Disclosures [Line Items]
Requested rate increase, amount	$ 19.7	$ 11.8

Regulatory Matters Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	$ 6,935	$ 7,024
Regulatory assets – current	77	100
Total Regulatory Assets	7,012	7,124
Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,768	2,874
Future income tax
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,413	2,439
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	807	823
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	327	295
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	77	48
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	59	38
Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	54	44
Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	44	56
Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	40	43
Indian Point Energy Center program costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	40	50
Surcharge for New York State assessment
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	32	28
O&R property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	32	37
Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	26	29
Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	25	25
Net electric deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	17	24
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	15	42
Regulatory assets – current	6	9
Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	14	13
O&R transition bond charges
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	12	15
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	133	101
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	71	91
CECONY
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	6,404	6,473
Regulatory assets – current	68	90
Total Regulatory Assets	6,472	6,563
CECONY \| Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,612	2,730
CECONY \| Future income tax
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,302	2,325
CECONY \| Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	697	711
CECONY \| Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	311	280
CECONY \| Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	70	42
CECONY \| Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	32	7
CECONY \| Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	54	44
CECONY \| Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	3
CECONY \| Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	38	41
CECONY \| Indian Point Energy Center program costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	40	50
CECONY \| Surcharge for New York State assessment
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	30	26
CECONY \| O&R property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	0
CECONY \| Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	26	29
CECONY \| Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	25	25
CECONY \| Net electric deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	17	24
CECONY \| Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	15	38
Regulatory assets – current	3	4
CECONY \| Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	14	13
CECONY \| O&R transition bond charges
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	0
CECONY \| Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	121	85
CECONY \| Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	$ 65	$ 86

Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 1,886	$ 1,905
Regulatory liabilities – current	64	128
Total Regulatory Liabilities	1,950	2,033
Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	786	755
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	206	193
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	164	145
Property tax reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	148	178
Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	88	60
Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	80	95
Carrying charges on repair allowance and bonus depreciation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	55	68
New York State income tax rate change
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	53	61
Variable-rate tax-exempt debt – cost rate reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	43	55
Base rate change deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	31	40
Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	27	27
Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	22	39
Net utility plant reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	12	16
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	171	173
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	29	29
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	29	71
Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	6	28
CECONY
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,686	1,712
Regulatory liabilities – current	42	90
Total Regulatory Liabilities	1,728	1,802
CECONY \| Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	661	641
CECONY \| Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	177	162
CECONY \| Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	164	145
CECONY \| Property tax reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	148	178
CECONY \| Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	88	60
CECONY \| Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	80	95
CECONY \| Carrying charges on repair allowance and bonus depreciation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	54	67
CECONY \| New York State income tax rate change
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	52	60
CECONY \| Variable-rate tax-exempt debt – cost rate reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	38	48
CECONY \| Base rate change deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	31	40
CECONY \| Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	27	27
CECONY \| Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	13	28
CECONY \| Net utility plant reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	15
CECONY \| Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	143	146
CECONY \| Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	10	5
CECONY \| Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	27	61
CECONY \| Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	$ 5	$ 24

Capitalization - Additional Information (Details) - USD ($)	1 Months Ended	6 Months Ended
	Mar. 31, 2017	Jun. 30, 2017
Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value		$ 16,416,000,000
Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value		636,000,000
CECONY \| Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value		13,468,000,000
CECONY \| Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value		636,000,000
Tax-exempt debt		636,000,000
Variable Rate Term Loan Due 2018 \| Term Loan
Schedule of Capitalization [Line Items]
Amount of debt prepaid	$ 400,000,000
Debentures \| 2.00% Debentures Due 2020
Schedule of Capitalization [Line Items]
Debt Instrument, face amount	$ 400,000,000
Debt instrument, interest rate	2.00%
Debentures \| 3.875% Debentures Due 2047 \| CECONY
Schedule of Capitalization [Line Items]
Debt Instrument, face amount		$ 500,000,000
Debt instrument, interest rate		3.875%
Senior Notes \| 4.45% Senior Notes Due 2042 \| Con Edison Development
Schedule of Capitalization [Line Items]
Debt Instrument, face amount	$ 97,000,000
Debt instrument, interest rate	4.45%

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Unamortized debt expense	$ 139	$ 134
Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion) (a)	15,340	14,774
Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion) (a)	17,052	16,093
CECONY
Debt Instrument [Line Items]
Unamortized debt discount	116	113
CECONY \| Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion) (a)	12,570	12,073
CECONY \| Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion) (a)	$ 14,104	$ 13,268

Short-Term Borrowing (Details) - USD ($)	Jun. 30, 2017	Dec. 31, 2016
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 1,036,000,000	$ 1,054,000,000
Loans outstanding under the credit agreement	0	0
Letters of credit outstanding under the credit agreement	$ 0	$ 2,000,000
Commercial Paper
Short-term Debt [Line Items]
Weighted average interest rate	1.30%	1.00%
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 750,000,000	$ 600,000,000
Letters of credit outstanding under the credit agreement	$ 0	$ 2,000,000
CECONY \| Commercial Paper
Short-term Debt [Line Items]
Weighted average interest rate	1.30%	1.00%

Pension Benefits - Total Periodic Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 66	$ 69	$ 132	$ 138
Interest cost on projected benefit obligation	148	149	296	298
Expected return on plan assets	(243)	(237)	(484)	(474)
Recognition of net actuarial loss	149	149	297	298
Recognition of prior service costs	(4)	1	(9)	2
TOTAL PERIODIC BENEFIT COST	116	131	232	262
Cost capitalized	(51)	(53)	(94)	(106)
Reconciliation to rate level	(3)	13	(14)	26
Cost charged to operating expenses	62	91	124	182
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	61	65	123	129
Interest cost on projected benefit obligation	139	140	277	280
Expected return on plan assets	(229)	(225)	(459)	(449)
Recognition of net actuarial loss	141	141	282	282
Recognition of prior service costs	(5)	0	(10)	1
TOTAL PERIODIC BENEFIT COST	107	121	213	243
Cost capitalized	(48)	(50)	(88)	(99)
Reconciliation to rate level	(5)	14	(16)	26
Cost charged to operating expenses	$ 54	$ 85	$ 109	$ 170

Pension Benefits - Additional Information (Details) $ in Millions	6 Months Ended
	Jun. 30, 2017 USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Estimated future employer contributions	$ 450
Contributions	283
Pension Benefits \| CECONY
Defined Benefit Plan Disclosure [Line Items]
Estimated future employer contributions	412
External Trust Supplemental Plans \| CECONY
Defined Benefit Plan Disclosure [Line Items]
Contributions	$ 14

Other Postretirement Benefits - Total Periodic Postretirement Benefit Costs (Details) - Other Postretirement Benefits - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 5	$ 4	$ 10	$ 9
Interest cost on accumulated other postretirement benefit obligation	11	12	23	24
Expected return on plan assets	(17)	(19)	(35)	(38)
Recognition of net actuarial loss/(gain)	1	1	1	2
Recognition of prior service cost	(4)	(5)	(8)	(10)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	(4)	(7)	(9)	(13)
Cost capitalized	2	2	4	3
Reconciliation to rate level	(1)	7	(2)	14
Cost charged to operating expenses	(3)	2	(7)	4
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	3	7	7
Interest cost on accumulated other postretirement benefit obligation	10	10	19	20
Expected return on plan assets	(15)	(17)	(30)	(34)
Recognition of net actuarial loss/(gain)	(1)	1	(2)	1
Recognition of prior service cost	(3)	(3)	(6)	(7)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	(6)	(6)	(12)	(13)
Cost capitalized	3	2	5	3
Reconciliation to rate level	(1)	6	(1)	14
Cost charged to operating expenses	$ (4)	$ 2	$ (8)	$ 4

Other Postretirement Benefits - Additional Information (Details) - Other Postretirement Benefits $ in Millions	Jun. 30, 2017 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 16
CECONY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 8

Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Site Contingency [Line Items]
Accrued Liabilities	$ 745	$ 753
Regulatory assets	7,012	7,124
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	659	664
Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	86	89
Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	745	753
Regulatory assets	807	823
CECONY
Site Contingency [Line Items]
Accrued Liabilities	651	655
Regulatory assets	6,472	6,563
CECONY \| Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	565	567
CECONY \| Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	86	88
CECONY \| Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	651	655
Regulatory assets	$ 697	$ 711

Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 7	$ 9	$ 14	$ 12
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 4	$ 3	$ 11	$ 5

Environmental Matters - Additional Information (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Site Contingency [Line Items]
Insurance recoveries	$ 0	$ 0	$ 0	$ 0
CECONY
Site Contingency [Line Items]
Insurance recoveries	$ 0	$ 0	$ 0	$ 0
CECONY \| Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)			15 years
Superfund Sites \| Manufactured Gas Plant Sites \| Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)					$ 2,800,000,000
Superfund Sites \| Manufactured Gas Plant Sites \| Maximum \| CECONY
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)					$ 2,600,000,000

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Site Contingency [Line Items]
Regulatory assets	$ 7,012	$ 7,124
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers’ Compensation
Site Contingency [Line Items]
Accrued liability	89	88
Regulatory assets	14	13
CECONY
Site Contingency [Line Items]
Regulatory assets	6,472	6,563
CECONY \| Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY \| Workers’ Compensation
Site Contingency [Line Items]
Accrued liability	85	83
Regulatory assets	$ 14	$ 13

Other Material Contingencies - Manhattan Steam Main Rupture (Details) - Manhattan Steam Main Rupture - CECONY $ in Millions	1 Months Ended
	Jul. 31, 2007 person	Jun. 30, 2017 USD ($) lawsuit
Loss Contingencies [Line Items]
Number of person who died in stream rupture incident \| person	1
Number of pending lawsuits \| lawsuit		45
Estimated accrued liability for suits		$ 18
Insurance receivable for suits		$ 18

Other Material Contingencies Other Material Contingencies - Manhattan Explosion and Fire (Details) $ in Millions		1 Months Ended
	Mar. 12, 2014 building people	Feb. 28, 2017 USD ($)	Jun. 30, 2017 USD ($) lawsuit	Dec. 31, 2016 USD ($)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 1,886	$ 1,905
Settlement of Gas Proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 27	$ 27
Manhattan Explosion and Fire
Loss Contingencies [Line Items]
Number of buildings destroyed by fire \| building	2
Number of people died in explosion and fire incident \| people	8
Number of people injured in explosion and fire incident (more than) \| people	50
Amount of costs that will not recover from customers		$ 126
Number of pending lawsuits \| lawsuit			80
Manhattan Explosion and Fire \| Settlement of Gas Proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 27

Other Material Contingencies - Total Guarantees (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 2,329	$ 2,370
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,047
Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	743
Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	411
Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	128
0 – 3 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,660
0 – 3 years \| Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	643
0 – 3 years \| Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	497
0 – 3 years \| Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	392
0 – 3 years \| Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	128
4 – 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	435
4 – 10 years \| Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	404
4 – 10 years \| Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	31
4 – 10 years \| Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
4 – 10 years \| Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
Greater than 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	234
Greater than 10 years \| Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
Greater than 10 years \| Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	215
Greater than 10 years \| Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	19
Greater than 10 years \| Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 0

Other Material Contingencies Other Material Contingencies - Con Edison Transmission (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016	Dec. 31, 2014
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,329	$ 2,370
Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Ownership interest, percentage			45.70%
Estimated project cost percentage	175.00%
Financial Guarantee in Behalf of CET Gas for Proposed Gas Transmission Project
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 25

Other Material Contingencies Other Material Contingencies - Energy Transactions (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,329	$ 2,370
Financial and Performance Guarantee for Commodity Transactions During Period in which Con Edison Solutions Provides Transition Services
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 21

Other Material Contingencies Other Material Contingencies - Other (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,329	$ 2,370
Financial Guarantee for Indemnity Agreements for Surety Bonds
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	70
Certain Obligations Under Agreement to Sell the Retail Electric Supply Business
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	53
Financial Guarantee to Public Utility Commission of Texas
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 5

Income Tax (Details) - USD ($)	3 Months Ended		6 Months Ended
Income Tax (Details) - USD ($)	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Income Taxes Disclosure [Line Items]
Income tax expense	$ 102,000,000	$ 124,000,000	$ 330,000,000	$ 288,000,000
Effective tax rate	37.00%	35.00%	37.00%	35.00%
Deferred tax asset, net operating loss	$ 18,000,000		$ 18,000,000
Valuation allowance	0		0
Estimated liability for uncertain tax positions	40,000,000		40,000,000
Effective income tax rate reconciliation, uncertainty of taxes			33,000,000
Effective income tax rate reconciliation, uncertainty net of federal taxes			23,000,000
Unrecognized tax benefits that would have an impact on effective tax rate	19,000,000		19,000,000
Unrecognized tax benefits that would have an impact on effective tax rate, net of taxes	13,000,000		13,000,000
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate	23,000,000		23,000,000
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate, net of federal taxes	16,000,000		16,000,000
Penalties for uncertain tax positions	0		0
CECONY
Income Taxes Disclosure [Line Items]
Income tax expense	$ 91,000,000	$ 84,000,000	$ 309,000,000	$ 264,000,000
Effective tax rate	39.00%	34.00%	39.00%	36.00%
Estimated liability for uncertain tax positions	$ 21,000,000		$ 21,000,000
Effective income tax rate reconciliation, uncertainty of taxes			17,000,000
Effective income tax rate reconciliation, uncertainty net of federal taxes			12,000,000
Unrecognized tax benefits that would have an impact on effective tax rate	$ 2,000,000		$ 2,000,000

Financial Information by Business Segment (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Segment Reporting Information [Line Items]
Revenues	$ 2,633	$ 2,794	$ 5,861	$ 5,950
Depreciation and amortization	332	302	662	599
Operating income/(loss)	423	515	1,193	1,157
Clean Energy Businesses
Segment Reporting Information [Line Items]
Depreciation and amortization	18	10	36	19
Operating income/(loss)	18	109	34	58
Con Edison Transmission
Segment Reporting Information [Line Items]
Operating income/(loss)	(2)	(1)	(4)	(1)
CECONY
Segment Reporting Information [Line Items]
Revenues	2,293	2,281	5,149	4,913
Depreciation and amortization	296	275	591	547
Operating income/(loss)	387	392	1,091	1,033
CECONY \| Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	229	215	458	428
Operating income/(loss)	330	371	622	645
CECONY \| Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	45	39	90	78
Operating income/(loss)	83	48	374	301
CECONY \| Steam
Segment Reporting Information [Line Items]
Depreciation and amortization	22	21	43	41
Operating income/(loss)	(26)	(27)	95	87
O&R
Segment Reporting Information [Line Items]
Depreciation and amortization	17	17	35	33
Operating income/(loss)	19	13	71	66
O&R \| Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	13	13	25	24
Operating income/(loss)	14	14	27	32
O&R \| Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	4	4	10	9
Operating income/(loss)	5	(1)	44	34
Operating segment
Segment Reporting Information [Line Items]
Revenues	2,633	2,794	5,861	5,950
Operating segment \| Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	146	338	283	648
Operating segment \| CECONY
Segment Reporting Information [Line Items]
Revenues	2,293	2,281	5,149	4,913
Operating segment \| CECONY \| Electric
Segment Reporting Information [Line Items]
Revenues	1,817	1,892	3,610	3,665
Operating segment \| CECONY \| Gas
Segment Reporting Information [Line Items]
Revenues	388	304	1,153	905
Operating segment \| CECONY \| Steam
Segment Reporting Information [Line Items]
Revenues	88	85	386	343
Operating segment \| O&R
Segment Reporting Information [Line Items]
Revenues	195	175	433	390
Operating segment \| O&R \| Electric
Segment Reporting Information [Line Items]
Revenues	148	144	289	284
Operating segment \| O&R \| Gas
Segment Reporting Information [Line Items]
Revenues	47	31	144	106
Other
Segment Reporting Information [Line Items]
Revenues	(1)	0	(4)	(1)
Depreciation and amortization	1	0	0	0
Operating income/(loss)	1	2	1	1
Inter-segment
Segment Reporting Information [Line Items]
Revenues	0	(3)	0	(9)
Inter-segment \| Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	0	3	0	9
Inter-segment \| CECONY
Segment Reporting Information [Line Items]
Revenues	(24)	(26)	(48)	(56)
Inter-segment \| CECONY \| Electric
Segment Reporting Information [Line Items]
Revenues	4	4	8	9
Inter-segment \| CECONY \| Gas
Segment Reporting Information [Line Items]
Revenues	2	1	3	3
Inter-segment \| CECONY \| Steam
Segment Reporting Information [Line Items]
Revenues	$ 18	$ 21	$ 37	$ 44

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	$ (133)	$ (99)
Gross Amounts Offset	10	6
Net Amounts of Assets/ (Liabilities)	(123)	(93)
Margin deposits	7	7
Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)		(1)
CECONY
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	(119)	(95)
Gross Amounts Offset	8	9
Net Amounts of Assets/ (Liabilities)	(111)	(86)
Margin deposits	7	7
Fair Value of Derivative Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(153)	(138)
Gross Amounts Offset	89	61
Net Amounts of Assets/ (Liabilities)	(64)	(77)
Fair Value of Derivative Liabilities, Current \| CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(105)	(111)
Gross Amounts Offset	56	45
Net Amounts of Assets/ (Liabilities)	(49)	(66)
Fair Value of Derivative Liabilities, Non-current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(136)	(91)
Gross Amounts Offset	62	52
Net Amounts of Assets/ (Liabilities)	(74)	(39)
Fair Value of Derivative Liabilities, Non-current \| CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(119)	(77)
Gross Amounts Offset	53	44
Net Amounts of Assets/ (Liabilities)	(66)	(33)
Fair Value of Derivative Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(289)	(229)
Gross Amounts Offset	151	113
Net Amounts of Assets/ (Liabilities)	(138)	(116)
Fair Value of Derivative Liabilities \| CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(224)	(188)
Gross Amounts Offset	109	89
Net Amounts of Assets/ (Liabilities)	(115)	(99)
Fair Value of Derivative Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	93	81
Gross Amounts Offset	(78)	(64)
Net Amounts of Assets/ (Liabilities)	15	17
Fair Value of Derivative Assets, Current \| CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	52	52
Gross Amounts Offset	(48)	(45)
Net Amounts of Assets/ (Liabilities)	4	7
Fair Value of Derivative Assets, Non-current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	63	49
Gross Amounts Offset	(63)	(43)
Net Amounts of Assets/ (Liabilities)	0	6
Fair Value of Derivative Assets, Non-current \| CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	53	41
Gross Amounts Offset	(53)	(35)
Net Amounts of Assets/ (Liabilities)	0	6
Fair Value of Derivative Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	156	130
Gross Amounts Offset	(141)	(107)
Net Amounts of Assets/ (Liabilities)	15	23
Fair Value of Derivative Assets \| CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	105	93
Gross Amounts Offset	(101)	(80)
Net Amounts of Assets/ (Liabilities)	$ 4	$ 13

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (21)	$ 11	$ (25)	$ 8
Total deferred gains/(losses)	(27)	84	(94)	(75)
Net deferred gains/(losses)	(48)	95	(119)	(67)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(59)	27	(108)	(86)
Purchased power expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	45	0	(70)
Unrealized gain/(loss) on derivatives		97		35
Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(51)	(23)	(114)	(33)
Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(8)	5	6	17
Non-utility operating revenue
Pre-tax gain/(loss) recognized in income
Unrealized gain/(loss) on derivatives	(7)		(4)	(1)
Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(21)	10	(22)	7
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	1	(3)	1
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	22	68	20	38
Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(40)	(52)	(85)	(125)
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(9)	68	(29)	12
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(17)	9	(22)	4
Total deferred gains/(losses)	(27)	76	(85)	(69)
Net deferred gains/(losses)	(44)	85	(107)	(65)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0	0	0
CECONY \| Purchased power expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0	0	0
CECONY \| Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0	0	0
CECONY \| Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0	0	0
CECONY \| Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(17)	9	(19)	5
CECONY \| Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	0	(3)	(1)
CECONY \| Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	20	61	21	33
CECONY \| Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(39)	(47)	(78)	(113)
CECONY \| Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (8)	$ 62	$ (28)	$ 11

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details) gal in Thousands	Jun. 30, 2017 gal MMBTU MW MWh
Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount \| MWh	33,854,855
Capacity
Derivatives, Fair Value [Line Items]
Notional amount \| MW	9,319
Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount \| MMBTU	99,241,963
Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount \| gal	1,680
CECONY \| Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount \| MWh	31,442,175
CECONY \| Capacity
Derivatives, Fair Value [Line Items]
Notional amount \| MW	4,500
CECONY \| Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount \| MMBTU	91,970,000
CECONY \| Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount \| gal	1,680

Derivative Instruments and Hedging Activities - Additional Information (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 70
Makeup of net credit exposure with investment-grade counterparties	23
Makeup of net credit exposure non-investment grade/non-rated counterparties	21
Makeup of net credit exposure with commodity exchange brokers	13
Makeup of net credit exposure independent system operators	13
Interest Rate Swap
Investment Holdings [Line Items]
Derivative liabilities		$ 1
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	9
Makeup of net credit exposure with investment-grade counterparties	2
Makeup of net credit exposure with commodity exchange brokers	7
Clean Energy Businesses \| Coram \| Interest Rate Swap
Investment Holdings [Line Items]
Derivative, fixed interest rate		2.0855%
Derivative liabilities	$ 1	$ 1

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Details) $ in Millions	Jun. 30, 2017 USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 128
Collateral posted	41
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	16
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	99
Derivatives in net asset position additional collateral	14
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	12
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	113
Collateral posted	41
CECONY \| Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	15
CECONY \| Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	$ 84

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Interest Rate Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Total		$ 1
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Netting Adjustment	$ (25)	(24)
Total assets	402	363
Derivative Liabilities, Netting Adjustment	(42)	(38)
Total liabilities	138	117
Recurring \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	270	236
Total liabilities	3	4
Recurring \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	153	144
Total liabilities	163	145
Recurring \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	4	7
Total liabilities	14	6
Recurring \| Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Netting Adjustment	(25)	(24)
Net Amounts of Assets/ (Liabilities)	22	30
Derivative Liabilities, Netting Adjustment	(42)	(38)
Derivative Liabilities, Total	137	116
Recurring \| Commodity \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Netting Adjustment	2	(10)
Net Amounts of Assets/ (Liabilities)	11	20
Total assets	363	326
Derivative Liabilities, Netting Adjustment	(13)	(26)
Derivative Liabilities, Total	115	99
Recurring \| Commodity \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	6	14
Derivative Liabilities, Before Netting	3	4
Recurring \| Commodity \| Level 1 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	3	10
Total assets	244	210
Derivative Liabilities, Before Netting	1	1
Recurring \| Commodity \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	37	33
Derivative Liabilities, Before Netting	162	144
Recurring \| Commodity \| Level 2 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	5	19
Total assets	116	125
Derivative Liabilities, Before Netting	120	124
Recurring \| Commodity \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	4	7
Derivative Liabilities, Before Netting	14	6
Recurring \| Commodity \| Level 3 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	1	1
Total assets	1	1
Derivative Liabilities, Before Netting	7	0
Recurring \| Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Netting Adjustment	0	0
Net Amounts of Assets/ (Liabilities)	380	333
Recurring \| Other \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Netting Adjustment	0	0
Net Amounts of Assets/ (Liabilities)	352	306
Recurring \| Other \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	264	222
Recurring \| Other \| Level 1 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	241	200
Recurring \| Other \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	116	111
Recurring \| Other \| Level 2 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	111	106
Recurring \| Other \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	0	0
Recurring \| Other \| Level 3 \| CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, Before Netting	0	0
Recurring \| Interest Rate Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Netting Adjustment	0	0
Derivative Liabilities, Total	1	1
Recurring \| Interest Rate Swap \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Before Netting	0	0
Recurring \| Interest Rate Swap \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Before Netting	1	1
Recurring \| Interest Rate Swap \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, Before Netting	$ 0	$ 0

Fair Value Measurements - Schedule of Commodity Derivatives (Details) - Level 3 $ in Millions	6 Months Ended
	Jun. 30, 2017 USD ($) $ / kW-month $ / MWh
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ (10)
CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	(6)
Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	(11)
Electricity \| CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ (7)
Electricity \| Forward Energy Prices \| Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) \| $ / MWh	15.89
Electricity \| Forward Energy Prices \| Minimum \| CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) \| $ / MWh	22.50
Electricity \| Forward Energy Prices \| Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) \| $ / MWh	79.00
Electricity \| Forward Energy Prices \| Maximum \| CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) \| $ / MWh	77.25
Electricity \| Forward Capacity Prices \| Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per kW-month) \| $ / kW-month	2.42
Electricity \| Forward Capacity Prices \| Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per kW-month) \| $ / kW-month	9.75
Transmission Congestion Contracts/Financial Transmission Rights
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ 1
Transmission Congestion Contracts/Financial Transmission Rights \| Discount for Inter Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	50.00%
Transmission Congestion Contracts/Financial Transmission Rights \| Inter Zonal Forward Price Curves Adjusted for Historical Zonal Losses \| Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) \| $ / MWh	0.50
Transmission Congestion Contracts/Financial Transmission Rights \| Inter Zonal Forward Price Curves Adjusted for Historical Zonal Losses \| Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) \| $ / MWh	9.30
Transmission Congestion Contracts
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives \| $	$ 1
Transmission Congestion Contracts \| Discount for Inter Zonal Forward Price Curves \| CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	50.00%

Fair Value Measurements - Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 3	$ (4)	$ 1	$ 6
Included in earnings	2	5	1	(2)
Included in regulatory assets and liabilities	(11)	1	(9)	(2)
Purchases	0	1	1	1
Settlements	(4)	2	(4)	2
Ending balance	(10)	5	(10)	5
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	1	2	1	8
Included in earnings	1	0	0	(1)
Included in regulatory assets and liabilities	(7)	(1)	(7)	(5)
Purchases	0	1	1	1
Settlements	(1)	0	(1)	(1)
Ending balance	$ (6)	$ 2	$ (6)	$ 2

Fair Value Measurements - Additional Information (Details) - Clean Energy Businesses - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Non-utility revenue
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 commodity derivative assets and liabilities	$ 0	$ 0	$ 0	$ 0
Change in fair value relating to Level 3 commodity derivative assets and liabilities	0	0	0	0
Purchased power expense
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 commodity derivative assets and liabilities	(1)	5	(1)	(2)
Change in fair value relating to Level 3 commodity derivative assets and liabilities	$ (2)	$ 7	$ (2)	$ 3

Variable Interest Entities (Details) $ in Millions	6 Months Ended
Variable Interest Entities (Details) $ in Millions	Jun. 30, 2017 USD ($) MW
Variable Interest Entity, Not Primary Beneficiary \| Copper Mountain Solar 3 \| Nevada
Variable Interest Entity [Line Items]
Generating Capacity (MW AC) \| MW	128
Power Purchase Agreement Term (in Years)	20 years
Maximum Exposure to Loss	$ 176
Variable Interest Entity, Not Primary Beneficiary \| Mesquite Solar 1 \| Arizona
Variable Interest Entity [Line Items]
Generating Capacity (MW AC) \| MW	83
Power Purchase Agreement Term (in Years)	20 years
Maximum Exposure to Loss	$ 102
Variable Interest Entity, Not Primary Beneficiary \| Copper Mountain Solar 2 \| Nevada
Variable Interest Entity [Line Items]
Generating Capacity (MW AC) \| MW	75
Power Purchase Agreement Term (in Years)	25 years
Maximum Exposure to Loss	$ 83
Variable Interest Entity, Not Primary Beneficiary \| California Solar \| California
Variable Interest Entity [Line Items]
Generating Capacity (MW AC) \| MW	55
Power Purchase Agreement Term (in Years)	25 years
Maximum Exposure to Loss	$ 62
Variable Interest Entity, Not Primary Beneficiary \| Broken Bow II \| Nebraska
Variable Interest Entity [Line Items]
Generating Capacity (MW AC) \| MW	38
Power Purchase Agreement Term (in Years)	25 years
Maximum Exposure to Loss	$ 46
Variable Interest Entity, Primary Beneficiary \| Texas Solar 4
Variable Interest Entity [Line Items]
Percentage of variable interests	80.00%
Maximum exposure for consolidated investments	$ 7
Variable Interest Entity, Primary Beneficiary \| Texas Solar 4 \| Texas
Variable Interest Entity [Line Items]
Generating Capacity (MW AC) \| MW	32
Power Purchase Agreement Term (in Years)	25 years
Maximum Exposure to Loss	$ 47
Variable Interest Entity, Not Primary Beneficiary, Aggregated Disclosure
Variable Interest Entity [Line Items]
Percentage of variable interests	50.00%

Dispositions (Details) - Con Edison Development $ in Millions	1 Months Ended	12 Months Ended
	May 31, 2017 USD ($)	Dec. 31, 2018 MW
Upton 2 \| Scenario, Forecast
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Project generating capacity (in mw) \| MW		180
Upton 2 \| Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Consideration the project is sold	$ 11.0
Gain on sale of project	1.0
Gain on sale of project, net of tax	$ 0.7