10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

x Quarterly Report Pursuant To Section 13 or 15(d) of the Securities Exchange Act of 1934

FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2017

OR

¨ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from to

Commission File Number	Exact name of registrant as specified in its charter and principal executive office address and telephone number	State of Incorporation	I.R.S. Employer ID. Number
1-14514	Consolidated Edison, Inc.	New York	13-3965100
	4 Irving Place, New York, New York 10003
	(212) 460-4600
1-1217	Consolidated Edison Company of New York, Inc.	New York	13-5009340
	4 Irving Place, New York, New York 10003
	(212) 460-4600

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Consolidated Edison, Inc. (Con Edison)	Yesx	No¨
Consolidated Edison Company of New York, Inc. (CECONY)	Yesx	No¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Con Edison	Yesx	No¨
CECONY	Yesx	No¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer”, “accelerated filer,” “smaller reporting company,” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Con Edison
Large accelerated filerx	Accelerated filer¨	Non-accelerated filer ¨
Smaller reporting company¨	Emerging growth company ¨
CECONY
Large accelerated filer¨	Accelerated filer¨	Non-accelerated filer x
Smaller reporting company¨	Emerging growth company ¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Con Edison	Yes¨	Nox
CECONY	Yes¨	Nox

As of July 31, 2017, Con Edison had outstanding 305,674,488 Common Shares ($.10 par value). All of the outstanding common equity of CECONY is held by Con Edison.

Filing Format

This Quarterly Report on Form 10-Q is a combined report being filed separately by two different registrants: Consolidated Edison, Inc. (Con Edison) and Consolidated Edison Company of New York, Inc. (CECONY). CECONY is a wholly-owned subsidiary of Con Edison and, as such, the information in this report about CECONY also applies to Con Edison. As used in this report, the term the “Companies” refers to Con Edison and CECONY. However, CECONY makes no representation as to the information contained in this report relating to Con Edison or the subsidiaries of Con Edison other than itself.

Glossary of Terms

The following is a glossary of abbreviations or acronyms that are used in the Companies’ SEC reports:

Con Edison Companies
Con Edison	Consolidated Edison, Inc.
CECONY	Consolidated Edison Company of New York, Inc.
Clean Energy Businesses	Con Edison Clean Energy Businesses, Inc., together with its subsidiaries
Con Edison Development	Consolidated Edison Development, Inc.
Con Edison Energy	Consolidated Edison Energy, Inc.
Con Edison Solutions	Consolidated Edison Solutions, Inc.
Con Edison Transmission	Con Edison Transmission, Inc., together with its subsidiaries
CET Electric	Consolidated Edison Transmission, LLC
CET Gas	Con Edison Gas Pipeline and Storage, LLC
O&R	Orange and Rockland Utilities, Inc.
RECO	Rockland Electric Company
The Companies	Con Edison and CECONY
The Utilities	CECONY and O&R
Regulatory Agencies, Government Agencies and Other Organizations
EPA	U.S. Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
IASB	International Accounting Standards Board
IRS	Internal Revenue Service
NJBPU	New Jersey Board of Public Utilities
NJDEP	New Jersey Department of Environmental Protection
NYISO	New York Independent System Operator
NYPA	New York Power Authority
NYSDEC	New York State Department of Environmental Conservation
NYSERDA	New York State Energy Research and Development Authority
NYSPSC	New York State Public Service Commission
NYSRC	New York State Reliability Council, LLC
PJM	PJM Interconnection LLC
SEC	U.S. Securities and Exchange Commission
Accounting
AFUDC	Allowance for funds used during construction
ASU	Accounting Standards Update
GAAP	Generally Accepted Accounting Principles in the United States of America
OCI	Other Comprehensive Income
VIE	Variable Interest Entity

3

Environmental
CO2	Carbon dioxide
GHG	Greenhouse gases
MGP Sites	Manufactured gas plant sites
PCBs	Polychlorinated biphenyls
PRP	Potentially responsible party
RGGI	Regional Greenhouse Gas Initiative
Superfund	Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes
Units of Measure
AC	Alternating current
Bcf	Billion cubic feet
Dt	Dekatherms
kV	Kilovolt
kWh	Kilowatt-hour
MDt	Thousand dekatherms
MMlb	Million pounds
MVA	Megavolt ampere
MW	Megawatt or thousand kilowatts
MWh	Megawatt hour
Other
AMI	Advanced metering infrastructure
COSO	Committee of Sponsoring Organizations of the Treadway Commission
DER	Distributed energy resources
EGWP	Employer Group Waiver Plan
Fitch	Fitch Ratings
First Quarter Form 10-Q	The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended March 31 of the current year
Second Quarter Form 10-Q	The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended June 30 of the current year
Form 10-K	The Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2016
LTIP	Long Term Incentive Plan
Moody’s	Moody’s Investors Service
REV	Reforming the Energy Vision
S&P	S&P Global Ratings
VaR	Value-at-Risk

4

4

TABLE OF CONTENTS

		PAGE
PART I—Financial Information
ITEM 1	Financial Statements (Unaudited)
	Con Edison
	Consolidated Income Statement	7
	Consolidated Statement of Comprehensive Income	8
	Consolidated Statement of Cash Flows	9
	Consolidated Balance Sheet	10
	Consolidated Statement of Equity	12
	CECONY
	Consolidated Income Statement	13
	Consolidated Statement of Comprehensive Income	14
	Consolidated Statement of Cash Flows	15
	Consolidated Balance Sheet	16
	Consolidated Statement of Shareholder’s Equity	18
	Notes to the Financial Statements (Unaudited)	19
ITEM 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	40
ITEM 3	Quantitative and Qualitative Disclosures About Market Risk	70
ITEM 4	Controls and Procedures	70
PART II—Other Information		71
ITEM 1	Legal Proceedings	71
ITEM 1A	Risk Factors	71
ITEM 6	Exhibits	71
	Signatures	72

5

FORWARD-LOOKING STATEMENTS

This report includes forward-looking statements intended to qualify for the safe-harbor provisions of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements are statements of future expectation and not facts. Words such as “forecasts,” “expects,” “estimates,” “anticipates,” “intends,” “believes,” “plans,” “will” and similar expressions identify forward-looking statements. Forward-looking statements are based on information available at the time the statements are made, and accordingly speak only as of that time. Actual results or developments might differ materially from those included in the forward-looking statements because of various factors including, but not limited to:

• the Companies are extensively regulated and are subject to penalties;

• the Utilities’ rate plans may not provide a reasonable return;

• the Companies may be adversely affected by changes to the Utilities’ rate plans;

• the intentional misconduct of employees or contractors could adversely affect the Companies;

• the failure of, or damage to, the Companies’ facilities could adversely affect the Companies;

• a cyber attack could adversely affect the Companies;

• the Companies are exposed to risks from the environmental consequences of their operations;

• a disruption in the wholesale energy markets or failure by an energy supplier could adversely affect the Companies;

• the Companies have substantial unfunded pension and other postretirement benefit liabilities;

• Con Edison’s ability to pay dividends or interest depends on dividends from its subsidiaries;

• the Companies require access to capital markets to satisfy funding requirements;

• changes to tax laws could adversely affect the Companies;

• the Companies’ strategies may not be effective to address changes in the external business environment; and

• the Companies also face other risks that are beyond their control.

6

6

ConsolidatedEdison, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended June 30,		For the Six Months Ended June 30,
	2017	2016	2017	2016
	(Millions of Dollars/ Except Per Share Data)
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	—	1	—
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	$0.57	$0.78	$1.84	$1.83
Net income per common share—diluted	$0.57	$0.77	$1.84	$1.82
DIVIDENDS DECLARED PER COMMON SHARE	$0.69	$0.67	$1.38	$1.34
AVERAGE NUMBER OF SHARES OUTSTANDING—BASIC (IN MILLIONS)	305.4	299.1	305.3	296.7
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS)	306.8	300.4	306.7	298.0

The accompanying notes are an integral part of these financial statements.

7

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended June 30,		For the Six Months Ended June 30,
	2017	2016	2017	2016
	(Millions of Dollars)
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	—	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	—	1
COMPREHENSIVE INCOME	$176	$233	$563	$543

The accompanying notes are an integral part of these financial statements.

8

8

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Six Months Ended June 30,
	2017	2016
	(Millions of Dollars)
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)	—
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)
Investments in electric and gas transmission projects	(16)	(79)
Investments in/acquisitions of renewable electric production projects	(1)	(1,171)
Proceeds from the transfer of assets to NY Transco	—	122
Proceeds from sale of assets	34	—
Restricted cash	28	(6)
Other investing activities	24	(82)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,703)	(2,986)
FINANCING ACTIVITIES
Net 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	—	702
Issuance of common shares for stock plans	25	27
Distribution to noncontrolling interest	—	(1)
NET CASH FLOWS FROM 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
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
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

The accompanying notes are an integral part of these financial statements. 

9

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	June 30, 2017	December 31, 2016
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$816	$776
Accounts receivable – customers, less allowance for uncollectible accounts of $63 and $69 in 2017 and 2016, respectively	984	1,106
Other receivables, less allowance for uncollectible accounts of $8 and $14 in 2017 and 2016, respectively	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
Electric	28,339	27,747
Gas	7,828	7,524
Steam	2,452	2,421
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 of $170 and $140 in 2017 and 2016, respectively	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

The accompanying notes are an integral part of these financial statements.

10

10

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	June 30, 2017	December 31, 2016
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDERS’ EQUITY
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

The accompanying notes are an integral part of these financial statements.

11

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF EQUITY (UNAUDITED)

(In Millions)	Common Stock		Additional Paid-In Capital	Retained Earnings	Treasury Stock		Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Noncontrolling Interest	Total
	Shares	Amount			Shares	Amount
BALANCE AS OF DECEMBER 31, 2015	293	$32	$5,030	$9,123	23	$(1,038)	$(61)	$(34)	$9	$13,061
Net income				310						310
Common stock dividends				(197)						(197)
Issuance of common shares for stock plans	1		28							28
Other comprehensive income										—
Noncontrolling interest									(1)	(1)
BALANCE AS OF MARCH 31, 2016	294	$32	$5,058	$9,236	23	$(1,038)	$(61)	$(34)	$8	$13,201
Net income				232						232
Common stock dividends				(204)						(204)
Issuance of common shares - public offering	10	1	723				(22)			702
Issuance of common shares for stock plans			26							26
Other comprehensive income								1		1
Noncontrolling interest										—
BALANCE AS OF JUNE 30, 2016	304	$33	$5,807	$9,264	23	$(1,038)	$(83)	$(33)	$8	$13,958
BALANCE AS OF DECEMBER 31, 2016	305	$33	$5,854	$9,559	23	$(1,038)	$(83)	$(27)	$8	$14,306
Net income				388						388
Common stock dividends				(211)						(211)
Issuance of common shares for stock plans			24							24
Other comprehensive loss								(1)		(1)
Noncontrolling interest										—
BALANCE AS OF MARCH 31, 2017	305	$33	$5,878	$9,736	23	$(1,038)	$(83)	$(28)	$8	$14,506
Net income				175						175
Common stock dividends				(210)						(210)
Issuance of common shares for stock plans	1		26							26
Other comprehensive income								1		1
Noncontrolling interest										—
BALANCE AS OF JUNE 30, 2017	306	$33	$5,904	$9,701	23	$(1,038)	$(83)	$(27)	$8	$14,498

The accompanying notes are an integral part of these financial statements.

12

12

Consolidated Edison Company of New York, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended June 30,		For the Six Months Ended June 30,
	2017	2016	2017	2016
	(Millions of Dollars)
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 and other 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	—
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

The accompanying notes are an integral part of these financial statements.

13

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended June 30,		For the Six Months Ended June 30,
	2017	2016	2017	2016
	(Millions of Dollars)
NET INCOME	$143	$161	$482	$472
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	—	1	—	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	—	1	—	1
COMPREHENSIVE INCOME	$143	$162	$482	$473

The accompanying notes are an integral part of these financial statements.

14

14

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Six Months Ended June 30,
	2017	2016
	(Millions of Dollars)
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)
Superfund and environmental remediation costs, net	(4)	67
Accrued taxes	(17)	(15)
Accrued taxes to affiliated companies	(119)	(2)
Accrued interest	—	(3)
System benefit charge	120	138
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	—	122
Restricted cash	—	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
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
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

The accompanying notes are an integral part of these financial statements. 

15

Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	June 30, 2017	December 31, 2016
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$767	$702
Accounts receivable – customers, less allowance for uncollectible accounts of $58 and $65 in 2017 and 2016, respectively	914	1,032
Other receivables, less allowance for uncollectible accounts of $7 and $13 in 2017 and 2016, respectively	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
Electric	26,687	26,122
Gas	7,095	6,814
Steam	2,452	2,421
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 PROPERTY
Non-utility property, less accumulated depreciation of $25 in 2017 and 2016	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

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	June 30, 2017	December 31, 2016
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$600		$—
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	—	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
SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	11,958	11,829
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$41,548	$40,856

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF SHAREHOLDER’S EQUITY (UNAUDITED)

	Common Stock		Additional Paid-In Capital	Retained Earnings	Repurchased Con Edison Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Total
(In Millions)	Shares	Amount
BALANCE AS OF DECEMBER 31, 2015	235	$589	$4,247	$7,611	$(962)	$(61)	$(9)	$11,415
Net income				310				310
Common stock dividend to parent				(186)				(186)
Capital contribution by parent			23					23
Other comprehensive income							—	—
BALANCE AS OF MARCH 31, 2016	235	$589	$4,270	$7,735	$(962)	$(61)	$(9)	$11,562
Net income				161				161
Common stock dividend to parent				(186)				(186)
Capital contribution by parent			28					28
Other comprehensive income							1	1
BALANCE AS OF JUNE 30, 2016	235	$589	$4,298	$7,710	$(962)	$(61)	$(8)	$11,566
BALANCE AS OF DECEMBER 31, 2016	235	$589	$4,347	$7,923	$(962)	$(61)	$(7)	$11,829
Net income				339				339
Common stock dividend to parent				(199)				(199)
Capital contribution by parent			22					22
Other comprehensive income								—
BALANCE AS OF MARCH 31, 2017	235	$589	$4,369	$8,063	$(962)	$(61)	$(7)	$11,991
Net income				143				143
Common stock dividend to parent				(199)				(199)
Capital contribution by parent			23					23
Other comprehensive income								—
BALANCE AS OF JUNE 30, 2017	235	$589	$4,392	$8,007	$(962)	$(61)	$(7)	$11,958

The accompanying notes are an integral part of these financial statements.

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NOTES TO THE FINANCIAL STATEMENTS (UNAUDITED)

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).

Note A – 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:

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	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.

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Note B — 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.

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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

Note C — 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,

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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.

Note D — 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.

Note E — 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

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	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.

Note F — 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

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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.

Note G — Environmental Matters

Superfund Sites

Hazardous substances, such as asbestos, polychlorinated biphenyls (PCBs) and coal tar, have been used or generated in the course of operations of the Utilities and their predecessors and are present at sites and in facilities and equipment they currently or previously owned, including sites at which gas was manufactured or stored.

The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances for investigation and remediation costs (which include costs of demolition, removal, disposal, storage, replacement, containment and monitoring) and natural resource damages. Liability under these laws can be material and may be imposed for contamination from past acts, even though such past acts may have been lawful at the time they occurred. The sites at which the Utilities have been asserted to have liability under these laws, including their manufactured gas plant sites and any neighboring areas to which contamination may have migrated, are referred to herein as “Superfund Sites.”

For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of the undiscounted cost to investigate the sites and, for sites that have been investigated in whole or in part, the cost to remediate the sites, if remediation is necessary and if a reasonable estimate of such cost can be made. Remediation costs are estimated in light of the information available, applicable remediation standards and experience with similar sites.

The accrued liabilities and regulatory assets related to Superfund Sites at 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

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	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

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Note H — Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately 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.

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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.

Note I — 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.

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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.

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Note J — 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.

Note K — 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.

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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.

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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).

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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.

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Note L — 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.

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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.

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	Fair Value of Level 3 at June 30, 2017	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
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 millionloss and $5 milliongain) 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 millionloss and $2 millionloss) 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 millionloss and $7 milliongain) 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

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commodity derivative assets and liabilities is included in non-utility revenues (immaterial for both periods) and purchased power costs ($2 millionloss and $3 milliongain) on the consolidated income statement, respectively.

Note M — 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.

Note N — 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.

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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

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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.

Note O — 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.

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Item 2: Management’s Discussion and Analysis of Financial Condition and Results of Operations

This combined management’s discussion and analysis of financial condition and results of operations (MD&A) relates to the consolidated financial statements (the Second Quarter Financial Statements) included in this report of two separate registrants: Consolidated Edison, Inc. (Con Edison) and Consolidated Edison Company of New York, Inc. (CECONY). As used in this report, the term the “Companies” refers to Con Edison and CECONY. CECONY is a subsidiary of Con Edison and, as such, information in this management’s discussion and analysis about CECONY applies to Con Edison.

This MD&A should be read in conjunction with the Second Quarter Financial Statements and the notes thereto, the MD&A in Item 7 of the Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2016 (File Nos. 1-14514 and 1-1217, the Form 10-K) and the MD&A in Part 1, Item 2 of the Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017 (File Nos. 1-14514 and 1-1217).

Information in any item of this report referred to in this discussion and analysis is incorporated by reference herein. The use of terms such as “see” or “refer to” shall be deemed to incorporate by reference into this discussion and analysis the information to which reference is made.

Con Edison, incorporated in New York State in 1997, is a holding company that owns all of the outstanding common stock of CECONY, Orange and Rockland Utilities, Inc. (O&R), Con Edison Clean Energy Businesses, Inc. and Con Edison Transmission, Inc. As used in this report, the term the “Utilities” refers to CECONY and O&R.

Con Edison’s principal business operations are those of CECONY, O&R, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business operations are its regulated electric, gas and steam delivery businesses. O&R’s principal business operations are its regulated electric and gas delivery businesses. The Clean Energy Businesses develop, own and operate renewable and energy infrastructure projects and provide energy-related products and services to wholesale and retail customers. Con Edison Transmission invests in electric transmission facilities and gas pipeline and storage facilities.

Con Edison seeks to provide shareholder value through continued dividend growth, supported by earnings growth in regulated utilities and contracted assets. The company invests to provide reliable, resilient, safe and clean energy critical for New York City’s growing economy. The company is an industry leading owner and operator of contracted, large-scale solar generation in the United States. Con Edison is a responsible neighbor, helping the communities it serves become more sustainable.

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CECONY

Electric

CECONY provides electric service to approximately 3.4 million customers in all of New York City (except a part of Queens) and most of Westchester County, an approximately 660 square mile service area with a population of more than nine million.

CECONY's 2016 service area peak demand was 12,652 MW, including an estimated 4,541 MW for CECONY's full-service customers, 6,114 MW for customers participating in its electric retail choice program and 1,997 MW for NYPA's electric commodity customers and municipal electric agency customers. The company estimates that, under design weather conditions, the 2017 service area peak demand will be 13,470 MW, including an estimated 4,912 MW for its full-service customers, 6,402 MW for its electric retail choice customers and 2,156 MW for NYPA's customers and municipal electric agency customers.

Gas

CECONY delivers gas to approximately 1.1 million customers in Manhattan, the Bronx, parts of Queens and most of Westchester County.

In May 2017, the company decreased its five-year forecast of average annual growth of the peak gas demand in its service area at design conditions from approximately 2.3 percent (for 2017 to 2021) to 1.6 percent (for 2018 to 2022). The decrease reflects, among other things, that in rolling the forecast forward a year, another year of oil-to-gas conversions has been completed and fewer opportunities to convert remain.

Steam

CECONY operates the largest steam distribution system in the United States by producing and delivering approximately 20,000 MMlb of steam annually to approximately 1,650 customers in parts of Manhattan.

O&R

Electric

O&R and its utility subsidiary, Rockland Electric Company (RECO) (together referred to herein as O&R) provide electric service to approximately 0.3 million customers in southeastern New York and northern New Jersey, an approximately 1,300 square mile service area.

Gas

O&R delivers gas to over 0.1 million customers in southeastern New York.

Clean Energy Businesses

Con Edison Clean Energy Businesses, Inc. has three wholly-owned subsidiaries: Consolidated Edison Development, Inc. (Con Edison Development), Consolidated Edison Energy, Inc. (Con Edison Energy) and Consolidated Edison Solutions, Inc. (Con Edison Solutions). Con Edison Clean Energy Businesses, Inc., together with these subsidiaries (which were formerly referred to as the competitive energy businesses), are referred to in this report as the Clean Energy Businesses.

In September 2016, Con Edison sold the retail electric supply business of its Clean Energy Businesses to a subsidiary of Exelon Corporation for cash consideration of $235 million. In addition, Con Edison received $23 million in cash as a working capital adjustment in February 2017.

In May 2017, Con Edison Development sold a development-stage solar electric production project for $11 million and agreed to perform engineering, procurement and construction for the project. See Note O to the Second Quarter Financial Statements.

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Con Edison Transmission

Con Edison Transmission, Inc. invests in electric and gas transmission projects through its wholly-owned subsidiaries, Consolidated Edison Transmission, LLC (CET Electric) and Con Edison Gas Pipeline and Storage, LLC (CET Gas). CET Electric owns a 45.7 percent interest in New York Transco LLC, which owns and is proposing to build additional electric transmission assets in New York. CET Gas owns, through subsidiaries, a 50 percent interest in a joint venture that owns, operates and will further develop an existing gas pipeline and storage business located in northern Pennsylvania and southern New York and a 71.2 percent interest in Honeoye Storage Corporation which operates a gas storage business in upstate New York. In addition, CET Gas owns a 12.5 percent interest in a company developing a proposed gas transmission project in West Virginia and Virginia. Con Edison Transmission, Inc., together with CET Electric and CET Gas, are referred to in this report as Con Edison Transmission.

Certain financial data of Con Edison’s businesses are presented below:

	For the Three Months Ended June 30, 2017						For the Six Months Ended June 30, 2017						At June 30, 2017
(Millions of Dollars, except percentages)	Operating Revenues			Net Income			Operating Revenues			Net Income			Assets
CECONY	$2,293	87	%	$143	82	%	$5,149	88	%	$482	86	%	$41,548	85	%
O&R	195	7		5	3		433	7		31	5		2,770	6
Total Utilities	2,488	94		148	85		5,582	95		513	91		44,318	91
Clean Energy Businesses (a)	146	6		21	12		283	5		28	5		2,773	6
Con Edison Transmission	—	—		9	5		—	—		16	3		1,170	2
Other (b)	(1)	—		(3)	(2	)	(4)	—		6	1		838	1
Total Con Edison	$2,633	100	%	$175	100	%	$5,861	100	%	$563	100	%	$49,099	100	%

(a) Net income from the Clean Energy Businesses includes for the three and six months ended June 30, 2017 $1 million net after-tax gain related to the sale of a development stage solar electric production project (see Note O to the Second Quarter Financial Statements). Also includes for the three and six months ended June 30, 2017 $4 million and $3 million of net after-tax mark-to-market losses, respectively.

(b) Other includes parent company and consolidation adjustments.

Results of Operations

Net income and earnings per share for the three and six months ended June 30, 2017 and 2016 were as follows:

	For the Three Months Ended June 30,								For the Six Months Ended June 30,
	2017	2016	2017			2016			2017	2016	2017		2016
(Millions of Dollars, except per share amounts)	Net Income		Earnings per Share						Net Income		Earnings per Share
CECONY	$143	$161		$0.47			$0.54		$482	$472		$1.58		$1.59
O&R	5	2	0.01			0.01			31	28	0.10		0.10
Clean Energy Businesses (a)	21	72	0.07			0.24			28	42	0.09		0.14
Con Edison Transmission	9	1	0.03			—			16	1	0.05		—
Other (b)	(3)	(4)	(0.01		)	(0.01		)	6	(1)	0.02		—
Con Edison (c)	$175	$232		$0.57			$0.78		$563	$542		$1.84		$1.83

(a) Includes $(4) million or $(0.01) a share and $58 million or $0.20 a share of net after-tax mark-to-market gains/(losses) for the three months ended June 30, 2017 and 2016, respectively, and $(3) million or $(0.01) a share and $20 million or $0.07 a share of net after-tax mark-to-market gains/(losses) for the six months ended June 30, 2017 and 2016, respectively. Substantially all the mark-to-market effects in the 2016 periods related to the retail electric supply business sold in September 2016.  Also includes a $1 million or $0.00 a share net after-tax gain on the sale of a solar electric production project for the three and six months ended June 30, 2017 (see Note O to the Second Quarter Financial Statements) and a $5 million or $0.02 a share net after-tax loss related to the impairment of a solar electric production investment for the three and six months ended June 30, 2016.

(b) Other includes parent company and consolidation adjustments.

(c) Earnings per share on a diluted basis were $0.57 a share and $0.77 a share for the three months ended June 30, 2017 and 2016, respectively, and $1.84 a share and $1.82 a share for the six months ended June 30, 2017 and 2016, respectively.

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The Companies’ results of operations for the three and six months ended June 30, 2017, as compared with the 2016 periods, reflect changes in the Utilities' rate plans and regulatory charges and the impact of weather on steam revenues. The new electric rate plan of CECONY includes changes in the timing of recognition of annual revenues between quarters. Other operations and maintenance expenses for CECONY reflect lower costs for pensions and other postretirement benefits and lower regulatory assessments and fees that are collected in revenues from customers, offset in part by higher costs for municipal infrastructure support. The rate plans provide for revenues to cover expected changes in certain operating costs including depreciation, property taxes and other tax matters. The results of operations also include the impact of the net mark-to-market effects of the Clean Energy Businesses.

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The following table presents the estimated effect on earnings per share and net income for the three and six months ended June 30, 2017 period as compared with 2016 period, resulting from these and other major factors:

	Three Months Variation		Six Months Variation
(Millions of Dollars, except per share amounts)	Earnings per Share Variation	Net Income  Variation	Earnings per Share Variation	Net Income  Variation
CECONY (a)
Changes in rate plans and regulatory charges (b)	$(0.04)	$(11)	$0.16	$48
Weather impact on steam revenues	—	(1)	0.02	5
Other operations and maintenance expenses (c)	0.13	38	0.16	48
Depreciation, property taxes and other tax matters (d)	(0.12)	(38)	(0.26)	(78)
Other (e)	(0.04)	(6)	(0.09)	(13)
Total CECONY	(0.07)	(18)	(0.01)	10
O&R (a)
Changes in rate plans and regulatory charges	0.03	7	0.04	11
Other operations and maintenance expenses (f)	(0.02)	(4)	(0.03)	(7)
Depreciation and property taxes	—	—	(0.01)	(2)
Other (e)	(0.01)	—	—	1
Total O&R	—	3	—	3
Clean Energy Businesses
Operating revenues less energy costs (g)	(0.15)	(46)	—	(1)
Other operations and maintenance expenses	(0.02)	(5)	(0.02)	(6)
Depreciation	(0.02)	(5)	(0.04)	(10)
Net interest expense	—	(2)	(0.01)	(4)
Other (e) (h)	0.02	7	0.02	7
Total Clean Energy Businesses	(0.17)	(51)	(0.05)	(14)
Con Edison Transmission (e) (i)	0.03	8	0.05	15
Other, including parent company expenses (e) (j)	—	1	0.02	7
Total variations	$(0.21)	$(57)	$0.01	$21

(a) Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans and the weather-normalization clause applicable to their gas businesses, revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. In general, the Utilities recover on a current basis the fuel, gas purchased for resale and purchased power costs they incur in supplying energy to their full-service customers. Accordingly, such costs do not generally affect the Companies' results of operations.

(b) For the three months ended June 30, 2017 as compared to the 2016 period, reflects lower electric net base revenues of $(0.05) a share, resulting from the timing of recognition of annual revenues between quarters under the company's new electric rate plan which reflected decreased assumed delivery volumes that offset increased base rates. For the six months ended June 30, 2017 as compared with the 2016 period, reflects higher electric net base revenues of $0.02 a share, as over the six month period increased base rates offset decreased assumed delivery volumes. Also, for the three and six months ended June 30, 2017 as compared with the 2016 periods, reflects higher gas net base revenues ($0.05 a share and $0.15 a share, respectively) and lower surcharges for assessments and fees that are collected in revenues from customers ($(0.03) a share and $(0.02) a share, respectively). For the six months ended June 30, 2017 as compared with the 2016 period, reflects growth in the number of gas customers of $0.02 a share.

(c) Reflects lower pension and other postretirement benefits costs of $0.07 a share and $0.15 a share as well as lower regulatory assessments and fees that are collected in revenues from customers of $0.03 a share and $0.02 a share for the three and six months ended June 30, 2017 as compared with the 2016 periods, offset, in part, by higher municipal infrastructure costs of $(0.01) a share and $(0.02) a share for the three and six months ended June 30, 2017 as compared with the 2016 periods.

(d) Reflects higher depreciation and amortization expense of $(0.04) a share and $(0.09) a share, property taxes of $(0.04) a share and $(0.09) a share, and income taxes of $(0.04) a share and $(0.08) a share for the three and six months ended June 30, 2017 as compared with the 2016 periods.

(e) Includes the impact of the dilutive effect of Con Edison's stock issuances.

(f) Reflects higher pension costs of $(0.01) a share and $(0.01) a share for the three and six months ended June 30, 2017 as compared with the 2016 periods. Also, for the six months ended June 30, 2017 as compared with the 2016 period, reflects higher regulatory assessments and fees that are collected from customers of $(0.01) a share.

(g) Reflects higher revenues from renewable electric production projects, offset by lower revenues from the retail electric supply business which was sold in September 2016.Includes $(0.01) a share and $0.20 a share of net after-tax mark-to-market gains/(losses) for the three months ended June 30, 2017 and 2016, respectively, and $(0.01) a share and $0.07 a share of net after-tax mark-to-market gains/(losses) for the six months ended June 30, 2017 and 2016, respectively. Substantially all the mark-to-market effects in the 2016 periods related to the retail electric supply business sold in September 2016.  

(h) Includes $0.02 a share of net after-tax loss related to the impairment of a solar electric production investment for the three and six months ended June 30, 2016.

(i) Reflects income from equity investments.

(j) Reflects higher state income tax benefits.

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The Companies’ other operations and maintenance expenses for the three and six months ended June 30, 2017 and 2016 were as follows:

	For the Three Months Ended June 30,		For the Six Months Ended June 30,
(Millions of Dollars)	2017	2016	2017	2016
CECONY
Operations	$377	$369	$761	$728
Pensions and other postretirement benefits	51	87	101	174
Health care and other benefits	42	44	82	78
Regulatory fees and assessments (a)	102	116	213	226
Other	66	85	144	175
Total CECONY	638	701	1,301	1,381
O&R	79	73	155	143
Clean Energy Businesses	56	47	94	84
Con Edison Transmission	2	1	4	1
Other (b)	(2)	(2)	(1)	(2)
Total other operations and maintenance expenses	$773	$820	$1,553	$1,607

(a) Includes Demand Side Management, System Benefit Charges and Public Service Law 18A assessments which are collected in revenues.

(b) Includes parent company and consolidation adjustments.

A discussion of the results of operations by principal business segment for the three and six months ended June 30, 2017 and 2016 follows. For additional business segment financial information, see Note J to the Second Quarter Financial Statements.

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Three Months Ended June 30, 2017 Compared with Three Months Ended June 30, 2016

The Companies’ results of operations in 2017 compared with 2016 were:

	CECONY			O&R			Clean Energy Businesses			Con Edison Transmission				Other (a)			Con Edison (b)
(Millions of Dollars)	Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount		Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent
Operating revenues	$12	0.5	%	$20	11.4	%	$(192)	(56.8	)%		$—	—	%	$(1)	—	%	$(161)	(5.8	)%
Purchased power	(6)	(1.6	)	1	2.2		(144)	Large		—		—		(1)	—		(150)	(26.9	)
Fuel	5	15.2		—	—		—	—		—		—		—	—		5	15.2
Gas purchased for resale	33	64.7		6	75.0		28	Large		—		—		1	Large		68	84.0
Other operations and maintenance	(63)	(9.0	)	6	8.2		9	19.1		1		Large		—	—		(47)	(5.7	)
Depreciation and amortization	21	7.6		—	—		8	80.0		—		—		1	—		30	9.9
Taxes, other than income taxes	27	5.9		1	5.3		(1)	(20.0	)	—		—		(1)	Large		26	5.4
Gain on sale of solar electric production project	—	—		—	—		1	—		—		—		—	—		1	—
Operating income	(5)	(1.3	)	6	46.2		(91)	(83.5	)	(1)		Large		(1)	(50.0	)	(92)	(17.9	)
Other income less deductions	(1)	(50.0	)	—	—		7	Large		17		Large		—	—		23	Large
Net interest expense	5	3.4		—	—		2	25.0		3		Large		—	—		10	5.9
Income before income tax expense	(11)	(4.5	)	6	Large		(86)	(79.6	)	13		Large		(1)	(50.0	)	(79)	(22.2	)
Income tax expense	7	8.3		3	Large		(35)	(97.2	)	5		—		(2)	Large		(22)	(17.7	)
Net income	$(18)	(11.2	)%	$3	Large		$(51)	(70.8	)%	$8		Large		$1	25.0	%	$(57)	(24.6	)%

(a) Includes parent company and consolidation adjustments.

(b) Represents the consolidated results of operations of Con Edison and its businesses.

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46

CECONY

	For the Three Months Ended June 30, 2017				For the Three Months Ended June 30, 2016
(Millions of Dollars)	Electric	Gas	Steam	2017 Total	Electric	Gas	Steam	2016 Total	2017-2016 Variation
Operating revenues	$1,817	$388	$88	$2,293	$1,892	$304	$85	$2,281	$12
Purchased power	358	—	5	363	364	—	5	369	(6)
Fuel	27	—	11	38	22	—	11	33	5
Gas purchased for resale	—	84	—	84	—	51	—	51	33
Other operations and maintenance	485	107	46	638	552	101	48	701	(63)
Depreciation and amortization	229	45	22	296	215	39	21	275	21
Taxes, other than income taxes	388	69	30	487	368	65	27	460	27
Operating income	$330	$83	$(26)	$387	$371	$48	$(27)	$392	$(5)

Electric

CECONY’s results of electric operations for the three months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$1,817	$1,892	$(75)
Purchased power	358	364	(6)
Fuel	27	22	5
Other operations and maintenance	485	552	(67)
Depreciation and amortization	229	215	14
Taxes, other than income taxes	388	368	20
Electric operating income	$330	$371	$(41)

CECONY’s electric sales and deliveries for the three months ended June 30, 2017 compared with the 2016 period were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
Residential/Religious (b)	2,062	2,141	(79	)	(3.7	)%		$546	$549	$(3)	(0.5	)%
Commercial/Industrial	2,090	2,180	(90	)	(4.1	)		429	415	14	3.4
Retail choice customers	5,934	6,056	(122	)	(2.0	)		593	601	(8)	(1.3	)
NYPA, Municipal Agency and other sales	2,330	2,377	(47	)	(2.0	)		146	139	7	5.0
Other operating revenues (c)	—	—	—		—			103	188	(85)	(45.2	)
Total	12,416	12,754	(338	)	(2.7	%)	(d)	$1,817	$1,892	$(75)	(4.0	%)

(a) Revenues from electric sales are subject to a revenue decoupling mechanism, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved.

(b) “Residential/Religious” generally includes single-family dwellings, individual apartments in multi-family dwellings, religious organizations and certain other not-for-profit organizations.

(c) Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the revenue decoupling mechanism and other provisions of the company’s rate plans.

(d) After adjusting for variations, primarily weather and billing days, electric delivery volumes in CECONY’s service area decreased 0.9 percent in the three months ended June 30, 2017 compared with the 2016 period.

47

Operating revenuesdecreased$75 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to lower revenues from the electric rate plan ($55 million) and lower purchased power expenses ($6 million), offset in part by higher fuel expenses ($5 million). The lower revenues included the timing of recognition of annual revenues between quarters under the new electric rate plan ($23 million) and the decline in surcharges for assessments and fees that were collected in revenues from customers ($15 million).

Purchased power expenses decreased$6 million in the three months ended June 30, 2017 compared with the 2016 period due to lower purchased volumes ($9 million), offset by higher unit costs ($3 million).

Fuel expenses increased$5 million in the three months ended June 30, 2017 compared with the 2016 period due to higher purchased volumes from the company's electric generating facilities ($3 million) and higher unit costs ($2 million).

Other operations and maintenance expenses decreased$67 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to lower pension and other post employment benefits costs ($38 million), surcharges for assessments and fees that are collected in revenues from customers ($15 million) and uncollectible expense ($6 million).

Depreciation and amortizationincreased$14 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher electric utility plant balances.

Taxes, other than income taxesincreased$20 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher property taxes ($16 million) and the absence in 2017 of a favorable state audit settlement in 2016 ($5 million).

Gas

CECONY’s results of gas operations for the three months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$388	$304	$84
Gas purchased for resale	84	51	33
Other operations and maintenance	107	101	6
Depreciation and amortization	45	39	6
Taxes, other than income taxes	69	65	4
Gas operating income	$83	$48	$35

CECONY’s gas sales and deliveries, excluding off-system sales, for the three months ended June 30, 2017 compared with the 2016 period were:

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48

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
Residential	10,303	9,692	611		6.3	%		$171	$140	$31	22.1	%
General	6,503	6,014	489		8.1			74	56	18	32.1
Firm transportation	14,771	14,409	362		2.5			102	88	14	15.9
Total firm sales and transportation	31,577	30,115	1,462		4.9		(b)	347	284	63	22.2
Interruptible sales (c)	2,109	1,815	294		16.2			9	5	4	80.0
NYPA	10,493	11,062	(569	)	(5.1	)		1	1	—	—
Generation plants	14,476	22,879	(8,403	)	(36.7	)		6	6	—	—
Other	4,073	4,682	(609	)	(13.0	)		7	8	(1)	(12.5	)
Other operating revenues (d)	—	—	—		—			18	—	18	—
Total	62,728	70,553	(7,825	)	(11.1	%)		$388	$304	$84	27.6	%

(a) Revenues from gas sales are subject to a weather normalization clause and a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

(b) After adjusting for variations, primarily billing days, firm gas sales and transportation volumes in the company’s service area increased 2.2 percent in the three months ended June 30, 2017 compared with the 2016 period, reflecting primarily increased volumes attributable to the growth in the number of gas customers.

(c) Includes 1,217 thousands and 915 thousands of Dt for the 2017 and 2016 periods, respectively, which are also reflected in firm transportation and other.

(d) Other gas operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plans.

Operating revenuesincreased$84 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher revenues from the gas rate plan and growth in the number of customers ($35 million) and higher gas purchased for resale expense ($33 million).

Gas purchased for resaleincreased$33 million in the three months ended June 30, 2017 compared with the 2016 period due to higher unit costs ($42 million), offset by lower purchased volumes ($9 million).

Other operations and maintenance expenses increased$6 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher pension and other post employment benefits costs ($4 million) and costs for maintenance of gas mains ($1 million).

Depreciation and amortizationincreased$6 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher gas utility plant balances.

Taxes, other than income taxesincreased $4 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher property taxes ($3 million) and payroll taxes ($1 million).

Steam

CECONY’s results of steam operations for the three months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$88	$85	$3
Purchased power	5	5	—
Fuel	11	11	—
Other operations and maintenance	46	48	(2)
Depreciation and amortization	22	21	1
Taxes, other than income taxes	30	27	3
Steam operating income	$(26)	$(27)	$1

49

CECONY’s steam sales and deliveries for the three months ended June 30, 2017 compared with the 2016 period were:

	Millions of Pounds Delivered							Revenues in Millions
	For the Three Months Ended							For the Three Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation		Percent Variation
General	58	68	(10	)	(14.7	)%		$4	$4		$—	—	%
Apartment house	1,032	1,094	(62	)	(5.7	)		26	26	—		—
Annual power	2,335	2,511	(176	)	(7.0	)		61	62	(1)		(1.6	)
Other operating revenues (a)	—	—	—		—			(3)	(7)	4		(57.1	)
Total	3,425	3,673	(248	)	(6.8	)%	(b)	$88	$85	$3		3.5	%

(a) Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan.

(b) After adjusting for variations, primarily weather and billing days, steam sales and deliveries decreased 2.6 percent in the three months ended June 30, 2017 compared with the 2016 period.

Operating revenuesincreased$3 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher revenues from the steam rate plan.

Other operations and maintenance expenses decreased$2 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to lower municipal infrastructure support costs.

Depreciation and amortization increased$1 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher steam utility plant balances.

Taxes, other than income taxesincreased$3 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher property taxes.

Other Income (Deductions)

Other income (deductions) decreased $1 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to an increase in other income deductions ($3 million), offset by an increase in investment and other income ($2 million).

Net Interest Expense

Net interest expense increased$5 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher long-term debt balances in the 2017 period.

Income Tax Expense

Income taxes increased$7 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to plant-related flow through items ($11 million) and a higher reserve for injuries and damages ($5 million), offset in part by lower income before income tax expense ($4 million), a decrease in bad debt expense ($3 million) and lower state income taxes ($2 million).

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50

O&R

	For the Three Months Ended June 30, 2017			For the Three Months Ended June 30, 2016
(Millions of Dollars)	Electric	Gas	2017 Total	Electric	Gas	2016 Total	2017-2016 Variation
Operating revenues	$148	$47	$195	$144	$31	$175	$20
Purchased power	46	—	46	45	—	45	1
Gas purchased for resale	—	14	14	—	8	8	6
Other operations and maintenance	62	17	79	60	13	73	6
Depreciation and amortization	13	4	17	13	4	17	—
Taxes, other than income taxes	13	7	20	12	7	19	1
Operating income	$14	$5	$19	$14	$(1)	$13		$6

Electric

O&R’s results of electric operations for the three months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$148	$144	$4
Purchased power	46	45	1
Other operations and maintenance	62	60	2
Depreciation and amortization	13	13	—
Taxes, other than income taxes	13	12	1
Electric operating income	$14	$14		$—

O&R’s electric sales and deliveries for the three months ended June 30, 2017 compared with the 2016 period were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
Residential/Religious (b)	359	366	(7	)	(1.9	)%		$69	$66	$3	4.5	%
Commercial/Industrial	177	197	(20	)	(10.2	)		27	28	(1)	(3.6	)
Retail choice customers	730	768	(38	)	(4.9	)		48	50	(2)	(4.0	)
Public authorities	24	23	1		4.3			2	2	—	—
Other operating revenues (c)	—	—	—		—			2	(2)	4	Large
Total	1,290	1,354	(64	)	(4.7	)%	(d)	$148	$144	$4	2.8	%

(a) O&R’s New York electric delivery revenues are subject to a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. O&R’s electric sales in New Jersey are not subject to a decoupling mechanism, and as a result, changes in such volumes do impact revenues.

(b) “Residential/Religious” generally includes single-family dwellings, individual apartments in multi-family dwellings, religious organizations and certain other not-for-profit organizations.

(c) Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s electric rate plan.

(d) After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased 2.3 percent in the three months ended June 30, 2017 compared with the 2016 period.

Operating revenuesincreased$4 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher revenues from the New York electric rate plan ($3 million) and higher purchased power expenses ($1 million).

Purchased power expenses increased$1 million in the three months ended June 30, 2017 compared with the 2016 period due to higher purchased volumes ($3 million), offset by lower unit costs ($2 million).

51

Other operations and maintenance expenses increased$2 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to a higher reserve for injuries and damages, higher surcharges for assessments and fees that are collected in revenues from customers, and operating costs related to weather events in 2017.

Taxes, other than income taxesincreased$1 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher property taxes.

Gas

O&R’s results of gas operations for the three months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$47	$31	$16
Gas purchased for resale	14	8	6
Other operations and maintenance	17	13	4
Depreciation and amortization	4	4	—
Taxes, other than income taxes	7	7	—
Gas operating income	$5	$(1)	$6

O&R’s gas sales and deliveries, excluding off-system sales, for the three months ended June 30, 2017 compared with the 2016 period were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
Residential	1,092	1,150	(58	)	(5.0	)%		$19	$12	$7	58.3	%
General	292	281	11		3.9			4	1	3	Large
Firm transportation	1,457	1,722	(265	)	(15.4	)		13	12	1	8.3
Total firm sales and transportation	2,841	3,153	(312	)	(9.9	)	(b)	36	25	11	44.0
Interruptible sales	959	946	13		1.4			1	1	—	—
Generation plants	1	11	(10	)	(90.9	)		—	—	—	—
Other	118	132	(14	)	(10.6	)		1	—	1	—
Other gas revenues	—	—	—		—			9	5	4	80.0
Total	3,919	4,242	(323	)	(7.6	)%		$47	$31	$16	51.6	%

(a) Revenues from New York gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

(b) After adjusting for weather and other variations, total firm sales and transportation volumes decreased 0.5 percent in the three months ended June 30, 2017 compared with 2016 period.

Operating revenuesincreased$16 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher revenues from the New York gas rate plan ($9 million) and increased gas purchased for resale ($6 million).

Gas purchased for resaleincreased$6 million in the three months ended June 30, 2017 compared with the 2016 period due to higher purchased volumes ($9 million), offset by lower unit costs ($3 million).

Other operations and maintenance expenses increased$4 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher pension costs.

Income Tax Expense

Income taxes increased$3 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher income before income tax expense.

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52

Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the three months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$146	$338	$(192)
Purchased power	—	144	(144)
Gas purchased for resale	51	23	28
Other operations and maintenance	56	47	9
Depreciation and amortization	18	10	8
Taxes, other than income taxes	4	5	(1)
Gain on sale of solar electric production project (a)	1	—	1
Operating income	$18	$109	$(91)

(a)     See Note O to the Second Quarter Financial Statements.

Operating revenuesdecreased$192 million in the three months ended June 30, 2017 compared with the 2016 period, due primarily to lower electric retail revenues of $263 million from the sale of the retail electric supply business in September 2016. Renewable revenues increased $36 million due primarily to an increase in renewable electric production projects in operation. See "Con Edison Development," below. Energy services revenues increased $7 million. Wholesale revenues increased $35 million due to higher sales volumes. Net mark-to-market values decreased $104 million, due primarily to the sale of the retail electric supply business, of which $97 million in losses are reflected in purchased power costs and $7 million in losses are reflected in revenues.

Purchased power expenses decreased$144 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to lower electric costs due to the sale of the retail electric supply business in September 2016 ($240 million), offset by changes in mark-to-market values ($96 million).

Gas purchased for resaleincreased$28 million in the three months ended June 30, 2017 compared with the 2016 period due to higher purchased volumes.

Other operations and maintenance expenses increased$9 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to an increase in energy services costs.

Depreciation and amortizationincreased$8 million in the three months ended June 30, 2017 compared with the 2016 period due to an increase in solar electric production projects in operation during 2017.

Taxes, other than income taxesdecreased $1 million in the three months ended June 30, 2017 compared with the 2016 period primarily due to lower gross receipts tax from the sale of the retail electric supply business.

Other Income (Deductions)

Other income (deductions) increased$7 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to the impairment of a solar electric production investment in 2016 of $8 million.

Net Interest Expense

Net interest expense increased$2 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to increased debt on solar electric production projects.

Income Tax Expense

Income taxes decreased$35 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to lower income before income tax expense.

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Con Edison Transmission

Net Interest Expense

Net interest expense increased $3 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to a new debt issuance in 2016.

Other Income (Deductions)

Other income (deductions) increased$17 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to earnings from equity investments in Stagecoach Gas Services, LLC, substantially all of which were made in June 2016.

Income Tax Expense

Income taxes increased $5 million in the three months ended June 30, 2017 compared with the 2016 period due primarily to higher income before income tax expense.

Other

For Con Edison, “Other” includes parent company and consolidation adjustments.

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54

Six Months Ended June 30, 2017 Compared with Six Months Ended June 30, 2016

The Companies’ results of operations in 2017 compared with 2016 were:

	CECONY			O&R			Clean Energy Businesses			Con Edison Transmission				Other (a)		Con Edison (b)
(Millions of Dollars)	Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount		Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent	Increases (Decreases) Amount	Increases (Decreases) Percent
Operating revenues	$236	4.8	%	$43	11.0	%	$(365)	(56.3	)%		$—	—	%	$(3)	Large	$(89)	(1.5	)%
Purchased power	(11)	(1.5	)	3	3.5		(445)	Large		—		—		(3)	—	(456)	(36.5	)
Fuel	35	33.7		—	—		—	—		—		—		—	—	35	33.7
Gas purchased for resale	131	71.6		19	82.6		81	Large		—		—		—	—	231	96.7
Other operations and maintenance	(80)	(5.8	)	12	8.4		10	11.9		3		Large		1	50.0	(54)	(3.4	)
Depreciation and amortization	44	8.0		2	6.1		17	89.5		—		—		—	—	63	10.5
Taxes, other than income taxes	59	6.3		2	5.0		(3)	(27.3	)	—		—		(1)	—	57	5.7
Gain on sale of solar electric production project	—	—		—	—		1	—		—		—		—	—	1	—
Operating income	58	5.6		5	7.6		(24)	(41.4	)	(3)		Large		—	—	36	3.1
Other income less deductions	6	—		—	—		6	66.7		36		Large		—	—	48	Large
Net interest expense	9	3.0		(1)	(5.3	)	6	37.5		7		Large		—	—	21	6.2
Income before income tax expense	55	7.5		6	12.8		(24)	(47.1	)	26		Large		—	—	63	7.6
Income tax expense	45	17.0		3	15.8		(10)	Large		11		—		(7)	Large	42	14.6
Net income	$10	2.1	%	$3	10.7	%	$(14)	(33.3	%)	$15		Large		$7	Large	$21	3.9	%

(a) Includes parent company and consolidation adjustments.

(b) Represents the consolidated results of operations of Con Edison and its businesses.

55

CECONY

	For the Six Months Ended June 30, 2017				For the Six Months Ended June 30, 2016
(Millions of Dollars)	Electric	Gas	Steam	2017 Total	Electric	Gas	Steam	2016 Total	2017-2016 Variation
Operating revenues	$3,610	$1,153	$386	$5,149	$3,665	$905	$343	$4,913	$236
Purchased power	691	—	19	710	705	—	16	721	(11)
Fuel	70	—	69	139	60	—	44	104	35
Gas purchased for resale	—	314	—	314	—	183	—	183	131
Other operations and maintenance	982	225	94	1,301	1,081	204	96	1,381	(80)
Depreciation and amortization	458	90	43	591	428	78	41	547	44
Taxes, other than income taxes	787	150	66	1,003	746	139	59	944	59
Operating income	$622	$374	$95	$1,091	$645	$301	$87	$1,033	$58

Electric

CECONY’s results of electric operations for the six months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Six Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$3,610	$3,665	$(55)
Purchased power	691	705	(14)
Fuel	70	60	10
Other operations and maintenance	982	1,081	(99)
Depreciation and amortization	458	428	30
Taxes, other than income taxes	787	746	41
Electric operating income	$622	$645	$(23)

CECONY’s electric sales and deliveries for the six months ended June 30, 2017 compared with the 2016 period were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Six Months Ended							For the Six Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
Residential/Religious (b)	4,339	4,476	(137	)	(3.1	)%		$1,120	$1,134	$(14)	(1.2	)%
Commercial/Industrial	4,395	4,471	(76	)	(1.7	)		859	830	29	3.5
Retail choice customers	12,238	12,269	(31	)	(0.3	)		1,225	1,196	29	2.4
NYPA, Municipal Agency and other sales	4,843	4,877	(34	)	(0.7	)		275	270	5	1.9
Other operating revenues (c)	—	—	—		—			131	235	(104)	(44.3	)
Total	25,815	26,093	(278	)	(1.1	)%	(d)	$3,610	$3,665	$(55)	(1.5	)%

(a) Revenues from electric sales are subject to a revenue decoupling mechanism, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved.

(b) “Residential/Religious” generally includes single-family dwellings, individual apartments in multi-family dwellings, religious organizations and certain other not-for-profit organizations.

(c) Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the revenue decoupling mechanism and other provisions of the company’s rate plans.

(d) After adjusting for variations, primarily weather and billing days, electric delivery volumes in CECONY’s service area decreased 0.6 percent in the six months ended June 30, 2017 compared with the 2016 period.

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Operating revenuesdecreased$55 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to lower revenues from the electric rate plan ($23 million) and lower purchased power costs ($14 million), offset in part by higher fuel expenses ($10 million). The lower revenues reflected the decline in surcharges for assessments and fees that were collected in revenues from customers ($19 million).

Purchased power expenses decreased$14 million in the six months ended June 30, 2017 compared with the 2016 period due to lower purchased volumes ($24 million), offset by higher unit costs ($10 million).

Fuel expenses increased$10 million in the six months ended June 30, 2017 compared with the 2016 period due to higher unit costs ($5 million) and purchased volumes from the company’s electric generating facilities ($5 million).

Other operations and maintenance expenses decreased$99 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to lower pension and other post employment benefits costs ($73 million) and surcharges for assessments and fees that are collected in revenues from customers ($19 million).

Depreciation and amortizationincreased$30 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher electric utility plant balances.

Taxes, other than income taxesincreased$41 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher property taxes ($32 million), the absence in 2017 of a favorable state audit settlement in 2016 ($5 million) and higher state and local taxes ($1 million).

Gas

CECONY’s results of gas operations for the six months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Six Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$1,153	$905	$248
Gas purchased for resale	314	183	131
Other operations and maintenance	225	204	21
Depreciation and amortization	90	78	12
Taxes, other than income taxes	150	139	11
Gas operating income	$374	$301	$73

CECONY’s gas sales and deliveries, excluding off-system sales, for the six months ended June 30, 2017 compared with the 2016 period were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Six Months Ended							For the Six Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
Residential	34,910	31,231	3,679		11.8	%		$509	$417	$92	22.1	%
General	19,306	16,997	2,309		13.6			206	160	46	28.8
Firm transportation	45,186	43,028	2,158		5.0			325	279	46	16.5
Total firm sales and transportation	99,402	91,256	8,146		8.9		(b)	1,040	856	184	21.5
Interruptible sales (c)	4,417	5,923	(1,506	)	(25.4	)		22	25	(3)	(12.0	)
NYPA	20,085	19,171	914		4.8			1	1	—	—
Generation plants	24,921	35,150	(10,229	)	(29.1	)		11	12	(1)	(8.3	)
Other	12,269	11,467	802		7.0			18	19	(1)	(5.3	)
Other operating revenues (d)	—	—	—		—			61	(8)	69	Large
Total	161,094	162,967	(1,873	)	(1.1	)%		$1,153	$905	$248	27.4	%

(a) Revenues from gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

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(b) After adjusting for variations, primarily billing days, firm gas sales and transportation volumes in the company’s service area increased 6.4 percent in the six months ended June 30, 2017 compared with the 2016 period, reflecting primarily increased volumes attributable to the growth in the number of gas customers.

(c) Includes 2,027 thousands and 3,376 thousands of Dt for the 2017 and 2016 periods, respectively, which are also reflected in firm transportation and other.

(d) Other gas operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plans.

Operating revenuesincreased$248 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher gas purchased for resale expense ($131 million) andhigher revenues from the gas rate plan and growth in the number of customers ($101 million).

Gas purchased for resaleincreased$131 million in the six months ended June 30, 2017 compared with the 2016 period due to higher unit costs.

Other operations and maintenance expenses increased$21 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher costs for maintenance of gas mains ($5 million), pension and other post employment benefits costs ($4 million), health and life expenses ($4 million), and municipal infrastructure support ($2 million).

Depreciation and amortizationincreased$12 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher gas utility plant balances.

Taxes, other than income taxesincreased$11 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher property taxes ($6 million), payroll taxes ($2 million), and state and local taxes ($2 million).

Steam

CECONY’s results of steam operations for the six months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Six Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$386	$343	$43
Purchased power	19	16	3
Fuel	69	44	25
Other operations and maintenance	94	96	(2)
Depreciation and amortization	43	41	2
Taxes, other than income taxes	66	59	7
Steam operating income	$95	$87	$8

CECONY’s steam sales and deliveries for the six months ended June 30, 2017 compared with the 2016 period were:

	Millions of Pounds Delivered							Revenues in Millions
	For the Six Months Ended							For the Six Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
General	351	334	17		5.1	%		$18	$16	$2	12.5	%
Apartment house	3,500	3,475	25		0.7			103	92	11	12.0
Annual power	7,634	7,691	(57	)	(0.7	)		258	235	23	9.8
Other operating revenues (a)	—	—	—		—			7	—	7	—
Total	11,485	11,500	(15	)	(0.1	)%	(b)	$386	$343	$43	12.5	%

(a) Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan.

(b) After adjusting for variations, primarily weather and billing days, steam sales and deliveries decreased 2.1 percent in the six months ended June 30, 2017 compared with the 2016 period.

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Operating revenuesincreased$43 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher fuel expenses ($25 million), the weather impact on revenues ($8 million), higher purchased power costs ($3 million), and higher revenues from the steam rate plan ($2 million).

Purchased power expenses increased$3 million in the six months ended June 30, 2017 compared with the 2016 period due to higher unit costs ($6 million), offset by lower purchased volumes ($3 million).

Fuel expenses increased$25 million in the six months ended June 30, 2017 compared with the 2016 period due to higher unit costs ($24 million) and purchased volumes from the company’s steam generating facilities ($1 million).

Other operations and maintenance expenses decreased$2 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to lower surcharges for assessments and fees that are collected in revenues from customers.

Depreciation and amortizationincreased$2 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher steam utility plant balances.

Taxes, other than income taxesincreased$7 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher property taxes ($5 million) and state and local taxes ($1 million).

Net Interest Expense

Net interest expense increased$9 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher long-term debt balances in the 2017 period.

Income Tax Expense

Income taxes increased$45 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher income before income tax expense ($22 million), a decrease in tax benefits for plant-related flow through items ($21 million), lower research and development tax credits ($8 million) and a higher reserve for injuries and damages ($6 million), offset in part by lower state income taxes ($6 million) and a decrease in bad debt expense ($4 million).

O&R

	For the Six Months Ended June 30, 2017			For the Six Months Ended June 30, 2016
(Millions of Dollars)	Electric	Gas	2017 Total	Electric	Gas	2016 Total	2017-2016 Variation
Operating revenues	$289	$144	$433	$284	$106	$390	$43
Purchased power	88	—	88	85	—	85	3
Gas purchased for resale	—	42	42	—	23	23	19
Other operations and maintenance	122	33	155	117	26	143	12
Depreciation and amortization	25	10	35	24	9	33	2
Taxes, other than income taxes	27	15	42	26	14	40	2
Operating income	$27	$44	$71	$32	$34	$66	$5

Electric

O&R’s results of electric operations for the six months ended June 30, 2017 compared with the 2016 period is as follows:

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	For the Six Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$289	$284	$5
Purchased power	88	85	3
Other operations and maintenance	122	117	5
Depreciation and amortization	25	24	1
Taxes, other than income taxes	27	26	1
Electric operating income	$27	$32	$(5)

O&R’s electric sales and deliveries for the six months ended June 30, 2017 compared with the 2016 period were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Six Months Ended							For the Six Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
Residential/Religious (b)	708	722	(14	)	(1.9	%)		$137	$131	$6	4.6	%
Commercial/Industrial	368	391	(23	)	(5.9	)		54	54	—	—
Retail choice customers	1,437	1,509	(72	)	(4.8	)		91	96	(5)	(5.2	)
Public authorities	48	45	3		6.7			4	4	—	—
Other operating revenues (c)	—	—	—		—			3	(1)	4	Large
Total	2,561	2,667	(106	)	(4.0	)%	(d)	$289	$284	$5	1.8	%

(a) O&R’s New York electric delivery revenues are subject to a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. O&R’s electric sales in New Jersey are not subject to a decoupling mechanism, and as a result, changes in such volumes do impact revenues.

(b) “Residential/Religious” generally includes single-family dwellings, individual apartments in multi-family dwellings, religious organizations and certain other not-for-profit organizations.

(c) Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s electric rate plan.

(d) After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased 1.4 percent in the six months ended June 30, 2017 compared with the 2016 period.

Operating revenuesincreased$5 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher revenues from the New York electric rate plan ($4 million) and higher purchased power expense ($3 million).

Purchased power expenses increased$3 million in the six months ended June 30, 2017 compared with the 2016 period due to higher purchased volumes ($4 million), offset by lower unit costs ($1 million).

Other operations and maintenance expenses increased$5 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher surcharges for assessments and fees that are collected in revenues from customers ($2 million), operating costs related to weather events in 2017 ($2 million), and a higher reserve for injuries and damages ($1 million).

Depreciation and amortizationincreased$1 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher electric utility plant balances.

Taxes, other than income taxesincreased$1 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher property taxes.

Gas

O&R’s results of gas operations for the six months ended June 30, 2017 compared with the 2016 period is as follows:

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	For the Six Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$144	$106	$38
Gas purchased for resale	42	23	19
Other operations and maintenance	33	26	7
Depreciation and amortization	10	9	1
Taxes, other than income taxes	15	14	1
Gas operating income	$44	$34	$10

O&R’s gas sales and deliveries, excluding off-system sales, for the six months ended June 30, 2017 compared with the 2016 period were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Six Months Ended							For the Six Months Ended
Description	June 30, 2017	June 30, 2016	Variation		Percent Variation			June 30, 2017	June 30, 2016	Variation	Percent Variation
Residential	4,977	4,712	265		5.6	%		$68	$46	$22	47.8	%
General	1,250	1,046	204		19.5			14	8	6	75.0
Firm transportation	5,645	6,297	(652	)	(10.4	)		42	41	1	2.4
Total firm sales and transportation	11,872	12,055	(183	)	(1.5	)	(b)	124	95	29	30.5
Interruptible sales	2,147	2,125	22		1.0			4	2	2	Large
Generation plants	2	12	(10	)	(83.3	)		—	—	—	—
Other	515	512	3		0.6			1	—	1	—
Other gas revenues	—	—	—		—			15	9	6	66.7	%
Total	14,536	14,704	(168	)	(1.1	)%		$144	$106	$38	35.8	%

(a) Revenues from New York gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

(b) After adjusting for weather and other variations, total firm sales and transportation volumes decreased 0.2 percent in the six months ended June 30, 2017 compared with 2016 period.

Operating revenues increased$38 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to an increase in gas purchased for resale ($19 million) and higher revenues from the New York gas rate plan ($16 million).

Gas purchased for resaleincreased$19 million in the six months ended June 30, 2017 compared with the 2016 period due to higher unit costs ($10 million) and higher purchased volumes ($9 million).

Other operations and maintenance expenses increased$7 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher pension costs.

Depreciation and amortizationincreased$1 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher gas utility plant balances.

Taxes, other than income taxesincreased$1 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher state and local taxes.

Income Tax Expense

Income taxes increased$3 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher income before income tax expense.

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Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the six months ended June 30, 2017 compared with the 2016 period is as follows:

	For the Six Months Ended
(Millions of Dollars)	June 30, 2017	June 30, 2016	Variation
Operating revenues	$283	$648	$(365)
Purchased power	(2)	443	(445)
Gas purchased for resale	114	33	81
Other operations and maintenance	94	84	10
Depreciation and amortization	36	19	17
Taxes, other than income taxes	8	11	(3)
Gain on sale of solar electric production project (a)	1	—	1
Operating income	$34	$58	$(24)

(a)     See Note O to the Second Quarter Financial Statements.

Operating revenuesdecreased$365 million in the six months ended June 30, 2017 compared with the 2016 period, due primarily to lower electric retail revenues of $525 million from the sale of the retail electric supply business in September 2016. Renewable revenues increased $56 million due primarily to an increase in renewable electric production projects in operation. See "Con Edison Development," below. Energy services revenues increased $12 million. Wholesale revenues increased $95 million due to higher sales volumes. Net mark-to-market values increased $38 million, due primarily to the sale of the retail electric supply business, of which $35 million in losses are reflected in purchased power costs and $3 million in losses are reflected in revenues.

Purchased power expenses decreased$445 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to lower electric costs due to the sale of the retail electric supply business in September 2016 ($480 million) offset by changes in mark-to-market values ($35 million).

Gas purchased for resaleincreased$81 million in the six months ended June 30, 2017 compared with the 2016 period due to higher purchased volumes.

Other operations and maintenance expenses increased$10 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to an increase in energy services costs.

Depreciation and amortizationincreased$17 million in the six months ended June 30, 2017 compared with the 2016 period due to an increase in solar electric production projects in operation during 2017.

Taxes, other than income taxesdecreased$3 million in the six months ended June 30, 2017 compared with the 2016 period due to lower gross receipts tax from the sale of the retail electric supply business in September 2016.

Other Income (Deductions)

Other income (deductions) increased$6 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to the impairment of a solar electric production investment in 2016 of $8 million.

Net Interest Expense

Net interest expense increased$6 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to increased debt on solar electric production projects.

Income Tax Expense

Income taxes decreased$10 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to lower income before income tax expense.

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Con Edison Transmission

Other Operations and Maintenance

Other operations and maintenance increased $3 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to CET having no employees or other direct costs until January 1, 2017.

Net Interest Expense

Net interest expense increased$7 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to a new debt issuance in 2016.

Other Income (Deductions)

Other income (deductions) increased$36 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to earnings from equity investments in Stagecoach Gas Services, LLC, substantially all of which were made in June 2016.

Income Tax Expense

Income taxes increased$11 million in the six months ended June 30, 2017 compared with the 2016 period due primarily to higher income before income tax expense.

Other

For Con Edison, “Other” includes parent company and consolidation adjustments.

Liquidity and Capital Resources

The Companies’ liquidity reflects cash flows from operating, investing and financing activities, as shown on their respective consolidated statement of cash flows and as discussed below.

Changes in the Companies’ cash and temporary cash investments resulting from operating, investing and financing activities for the six months ended June 30, 2017 and 2016 are summarized as follows:

	For the Six Months Ended June 30,
	Con Edison			CECONY
(Millions of Dollars)	2017	2016	Variation	2017	2016	Variation
Operating activities	$1,574	$1,631	$(57)	$1,234	$1,399	$(165)
Investing activities	(1,703)	(2,986)	1,283	(1,460)	(1,225)	(235)
Financing activities	169	1,273	(1,104)	291	(202)	493
Net change for the period	40	(82)	122	65	(28)	93
Balance at beginning of period	776	944	(168)	702	843	(141)
Balance at end of period	$816	$862	$(46)	$767	$815	$(48)

Cash Flows from Operating Activities

The Utilities’ cash flows from operating activities reflect primarily their energy sales and deliveries and cost of operations. The volume of energy sales and deliveries is affected primarily by factors external to the Utilities, such as growth of customer demand, weather, market prices for energy and economic conditions. Measures that promote distributed energy resources, such as distributed generation, demand reduction and energy efficiency, also affect the volume of energy sales and deliveries. Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans, changes in delivery volumes from levels assumed when rates were approved may affect the timing of cash flows but generally not net income. The prices at which the Utilities provide energy to their customers are determined in accordance with their rate plans. In general, changes in the Utilities’ cost of purchased power, fuel and gas may affect the timing of cash flows but not net income because the costs are recovered in accordance with rate plans.

Net income is the result of cash and non-cash (or accrual) transactions. Only cash transactions affect the Companies’ cash flows from operating activities. Principal non-cash charges or credits include depreciation, deferred income tax expense and amortizations of certain regulatory assets and liabilities. Non-cash charges or credits may also be accrued under the revenue decoupling and cost reconciliation mechanisms in the Utilities’ New York electric and gas rate plans.

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Net cash flows from operating activities for the six months ended June 30, 2017 for Con Edison and CECONY were $57 million and $165 million lower, respectively, than in the 2016 period. The change in net cash flows for Con Edison and CECONY reflects primarily lower cash paid, net of refunds received, for income taxes in the 2017 period as compared with the 2016 period of $107 million and $203 million, respectively. The income tax refund received in 2016 reflected the extension of bonus depreciation in late 2015, resulting in a refund of the 2015 estimated federal tax payments. This was offset in part by a change in the other current assets balance associated with the revenue decoupling mechanism in the 2017 period as compared with the 2016 period of $65 million and $69 million for Con Edison and CECONY, respectively.

The change in net cash flows also reflects the timing of payments for and recovery of energy costs. This timing is reflected within changes to accounts receivable – customers, recoverable and refundable energy costs within other regulatory assets and liabilities and accounts payable balances.

The changes in regulatory assets primarily reflect changes in deferred pension costs in accordance with the accounting rules for retirement benefits.

Cash Flows Used in Investing Activities

Net cash flows used in investing activities for Con Edison and CECONY were $1,283 million lower and $235 million higher, respectively, for the six months ended June 30, 2017 compared with the 2016 period. The change for Con Edison reflects primarily no new investments in renewable electric production projects ($1,170 million), a decrease in non-utility construction expenditures ($106 million) and investments in electric and gas transmission projects ($63 million), offset in part by increased utility construction expenditures in 2017 ($81 million). The change for CECONY reflects primarily increased utility construction expenditures ($73 million) and absence of proceeds from the transfer of assets to NY Transco in 2016 ($122 million).

Cash Flows From Financing Activities

Net cash flows from financing activities for Con Edison and CECONY were $1,104 million lower and $493 million higher, respectively, in the six months ended June 30, 2017 compared with the 2016 period.

In June 2017, CECONY issued $500 million aggregate principal amount of 3.875 percent debentures, due 2047, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes.

In March 2017, Con Edison issued $400 million aggregate principal amount of 2.00 percent debentures, due 2020, and prepaid the June 2016 $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 May 2016, Con Edison issued approximately 10 million common shares resulting in net proceeds, after issuance expenses, of $702 million and $500 million aggregate principal amount of 2.00 percent debentures, due 2021, the net proceeds from the sale of which were used in connection with the acquisition by a CET Gas subsidiary of a 50 percent equity interest in a gas pipeline and storage joint venture (see Con Edison Transmission, below) and for general corporate purposes.

In June 2016, CECONY issued $550 million aggregate principal amount of 3.85 percent debentures, due 2046, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes.

In June 2016, a Con Edison Solutions subsidiary borrowed $2 million pursuant to a loan agreement with a New Jersey utility. The borrowing matures in 2026, bears interest of 11.18 percent and may be repaid in cash or project Solar Renewable Energy Certificates.

In May 2016, a Con Edison Development subsidiary issued $95 million aggregate principal amount of 4.07 percent senior notes, due 2036, secured by the company's California Holdings 3 solar project.

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

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Con Edison’s cash flows from financing for six months ended June 30, 2017 and 2016 also reflect the proceeds, and reduction in cash used for reinvested dividends, resulting from the issuance of common shares under the company’s dividend reinvestment, stock purchase and long-term incentive plans of $50 million and $53 million, respectively.

Cash flows used in financing activities of the Companies also reflect commercial paper issuances and repayments. The commercial paper amounts outstanding at June 30, 2017 and 2016 and the average daily balances for the six months ended June 30, 2017 and 2016 for Con Edison and CECONY were as follows:

	2017		2016
(Millions of Dollars, except Weighted Average Yield)	Outstanding at June 30,	Daily average	Outstanding at June 30,	Daily average
Con Edison	$1,036	$699	$708	$992
CECONY	$750	$330	$608	$418
Weighted average yield	1.3%	1.0%	0.7%	0.6%

Capital Requirements and Resources

Con Edison has decreased its estimates for capital requirements for the retirement of long-term securities for 2018 from $1,688 million to $1,288 million. The decrease reflects the $400 million prepayment of a variable rate term loan that was to mature in 2018. See Note C to the Second Quarter Financial Statements.

For each of the Companies, the ratio of earnings to fixed charges (Securities and Exchange Commission basis) for the six months ended June 30, 2017 and 2016 and the twelve months ended December 31, 2016 was:

	Ratio of Earnings to Fixed Charges
	For the Six Months Ended June 30, 2017	For the Six Months Ended June 30, 2016	For the Twelve Months Ended December 31, 2016
Con Edison	3.3	3.2	3.6
CECONY	3.4	3.3	3.6

For each of the Companies, the common equity ratio at June 30, 2017 and December 31, 2016 was:

	Common Equity Ratio (Percent of total capitalization)
	June 30, 2017	December 31, 2016
Con Edison	49.6	49.3
CECONY	50.0	49.5

Other Changes in Assets and Liabilities

The following table shows changes in certain assets and liabilities at June 30, 2017, compared with December 31, 2016.

	Con Edison	CECONY
(Millions of Dollars)	2017 vs. 2016 Variation	2017 vs. 2016 Variation
Assets
Regulatory asset - Unrecognized pension and other postretirement costs	$(106)	$(118)
Liabilities
Pension and retiree benefits	$(195)	$(226)
Deferred income taxes and unamortized investment tax credits	344	343
System benefit charge	132	120

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Regulatory Asset for Unrecognized Pension and Other Postretirement Costs and Liability for Pension and Retiree Benefits

The decrease in the regulatory asset for unrecognized pension and other postretirement costs and the liability for pension and retiree benefits reflects the final actuarial valuation of the pension and other retiree benefit plans as measured at December 31, 2016, in accordance with the accounting rules for retirement benefits. The change in the regulatory asset also reflects the year’s amortization of accounting costs. The change in the liability for pension and retiree benefits reflects in part contributions to the plans made by the Utilities in 2017. See Notes E and F to the Second Quarter Financial Statements.

Deferred Income Taxes and Unamortized Investment Tax Credits

The increase in the liability for deferred income taxes and unamortized investment tax credits for Con Edison and CECONY reflects primarily bonus depreciation in 2017, partially offset by the increase in deferred income tax assets associated with the federal tax attribute carryforwards related to the net operating loss and general business tax credits. See Note I to the Second Quarter Financial Statements.

System Benefit Charge

The increase in the liability for the system benefit charge reflects amounts collected by the Utilities from their customers that will be required to be paid to NYSERDA.

Off-Balance Sheet Arrangements

None of the Companies’ transactions, agreements or other contractual arrangements meets the SEC definition of off-balance sheet arrangements.

Regulatory Matters

In March 2017, the NYSPSC issued an order that changes the way distributed energy resources are compensated and begins to phase out net energy metering. In New York, net energy metering compensates kilowatt-hours exported to the electric distribution system at the full service rate (that is production plus delivery plus taxes and fees). To provide a gradual transition, the NYSPSC allowed all existing resources to keep their current rate treatment and will delay making significant changes to policies affecting new residential and small commercial rooftop solar until 2020. Larger installations, including new commercial and industrial projects and new community solar projects, will be paid for the value of their exports to the electricity distribution system. The new policy establishes a 2 percent limit on bill increases, reducing the shifting of avoided distribution costs to non-participating residential customers that would have occurred under net energy metering.

For additional information about the Utilities’ regulatory matters, see Note B to the Second Quarter Financial Statements.

Environmental Matters

In May 2017, a transformer failure at a CECONY substation discharged thousands of gallons of transformer oil into the soil. Some of the transformer oil, which contained small amounts of polychlorinated biphenyls (PCBs), leaked into the East River. The company, the U.S. Coast Guard, the New York State Department of Environmental Conservation and other agencies responded to the incident. The company has replaced the transformer, and is continuing to remediate and monitor the site, the costs of which are not expected to have a material adverse effect on its financial condition, results of operations or liquidity. In connection with the incident, the company may incur monetary sanctions of more than $0.1 million for violations of certain  provisions regulating the discharge of materials into, and for the protection of, the environment.

In June 2017, CECONY received a notice of potential liability from the U.S. Environmental Protection Agency (EPA) with respect to the Newtown Creek site that was listed in 2010 on the EPA’s National Priorities List of Superfund sites. The EPA has identified fourteen potentially responsible parties (PRPs) with respect to the site, including CECONY, and has indicated that it will notify the company as additional PRPs are identified and notified by the EPA. Newtown Creek and its tributaries (collectively, Newtown Creek) form a 3.8 mile border between Brooklyn and Queens, New York. Currently, the predominant land use around Newtown Creek includes industrial, petroleum, recycling, manufacturing and distribution facilities and warehouses. Other uses include trucking, concrete manufacture, transportation infrastructure and a wastewater treatment plant. Newtown Creek is near several residential neighborhoods. Six PRPs, not including CECONY, pursuant to an administrative settlement agreement and order on consent the EPA issued to them in 2011, have been performing a remedial investigation of the site. The EPA indicated that sampling events have shown the sediments in Newtown Creek to be contaminated with a

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wide variety of hazardous substances including PCBs, metals, pesticides, polycyclic aromatic hydrocarbons and volatile organic contaminants. The EPA also indicated that it has reason to believe that hazardous substances have come to be released from CECONY facilities into Newtown Creek. The EPA’s current schedule anticipates completion of a feasibility study for the site by late 2018 and issuance of its record of decision selecting a remedy for the site by late 2020. CECONY is unable to estimate its exposure to liability for the Newtown Creek site.

For additional information about the Companies’ environmental matters, see Note G to the Second Quarter Financial Statements. 

Con Edison Development

The following table provides information about the renewable electric production projects Con Edison Development owned at June 30, 2017:

Project Name	Production Technology	Generating Capacity (a) (MW AC)	Purchased Power Agreement (PPA)Term (In Years) (b)	Actual/Expected In-Service Date (c)	Location (State)
Wholly owned projects
Pilesgrove	Solar	18	(d)	2011	New Jersey
Flemington Solar	Solar	8	(d)	2011	New Jersey
Frenchtown I, II and III	Solar	14	(d)	2011-13	New Jersey
PA Solar	Solar	10		2012	Pennsylvania
California Solar 2 (e)	Solar	80	20	2014-16	California
Oak Tree Wind	Wind	20	20	2014	South Dakota
Texas Solar 3	Solar	6	25	2015	Texas
Texas Solar 5 (e)	Solar	95	25	2015	Texas
Campbell County Wind	Wind	95	30	2015	South Dakota
Texas Solar 7 (e)	Solar	106	25	2016	Texas
California Solar 3 (e)	Solar	110	20	2016	California
Adams Wind (e)	Wind	23	7	2016	Minnesota
Valley View (e)	Wind	10	14	2016	Minnesota
Coram (e)	Wind	102	16	2016	California
Projects of less than 5 MW	Solar / Wind	25	Various	Various	Various
Jointly owned projects (e) (f)
California Solar	Solar	55	25	2012-13	California
Mesquite Solar 1	Solar	83	20	2013	Arizona
Copper Mountain Solar 2	Solar	75	25	2013-15	Nevada
Copper Mountain Solar 3	Solar	128	20	2014-15	Nevada
Broken Bow II	Wind	38	25	2014	Nebraska
Texas Solar 4	Solar	32	25	2014	Texas
Total MW (AC) in Operation		1,133
Upton County Solar (e)	Solar	158	25	2017	Texas
Panoche Valley	Solar	240	20	2018	California
Total MW (AC) in Construction		398
Total MW (AC), All Projects		1,531

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

(b) Represents PPA contractual term or remaining term from Con Edison Development’s date of acquisition.

(c) Represents Actual/Expected In-Service Date or Con Edison Development's date of acquisition.

(d) Have Solar Renewable Energy Credit hedges in place, in lieu of PPAs, out to 2020.

(e) Project has been pledged to secure financing for the project.

(f) All of the jointly-owned projects are 50 percent owned, except for Texas Solar 4 (which is 80 percent owned). See Note M to the Second

Quarter Financial Statements.

Con Edison Development's renewable electric production volumes generated for the three and six months ended June 30, 2017 compared with the 2016 period were:

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	Millions of kWh Generated
	For the Three Months Ended					For the Six Months Ended
Description	June 30, 2017	June 30, 2016	Variation	Percent Variation		June 30, 2017	June 30, 2016	Variation	Percent Variation
Renewable electric production projects
Solar	612	438	174	39.7	%	1,011	757	254	33.6	%
Wind	279	172	107	62.2	%	517	327	190	58.1	%
Total	891	610	281	46.1	%	1,528	1,084	444	41.0	%

Financial and Commodity Market Risks

The Companies are subject to various risks and uncertainties associated with financial and commodity markets. The most significant market risks include interest rate risk, commodity price risk, credit risk and investment risk.

Interest Rate Risk

The Companies’ interest rate risk relates primarily to variable rate debt and to new debt financing needed to fund capital requirements, including the construction expenditures of the Utilities and maturing debt securities. Con Edison and its businesses manage interest rate risk through the issuance of mostly fixed-rate debt with varying maturities and through opportunistic refinancing of debt. Con Edison and CECONY estimate that at June 30, 2017, a 10 percent increase in interest rates applicable to its variable rate debt would result in an increase in annual interest expense of $3 million. Under CECONY’s current electric, gas and steam rate plans, variations in actual variable rate tax-exempt debt interest expense are reconciled to levels reflected in rates.

Commodity Price Risk

Con Edison’s commodity price risk relates primarily to the purchase and sale of electricity, gas and related derivative instruments. The Utilities and the Clean Energy Businesses apply risk management strategies to mitigate their related exposures. See Note K to the Second Quarter Financial Statements.

Con Edison estimates that, as of June 30, 2017, a 10 percent decline in market prices would result in a decline in fair value of $55 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $48 million is for CECONY and $7 million is for O&R. Con Edison expects that any such change in fair value would be largely offset by directionally opposite changes in the cost of the electricity and gas purchased. In accordance with provisions approved by state regulators, the Utilities generally recover from customers the costs they incur for energy purchased for their customers, including gains and losses on certain derivative instruments used to hedge energy purchased and related costs.

The Clean Energy Businesses use a value-at-risk (VaR) model to assess the market price risk of their portfolio of electricity and gas commodity fixed-price purchase and sales commitments, physical forward contracts, generating assets and commodity derivative instruments. VaR represents the potential change in fair value of the portfolio due to changes in market prices, for a specified time period and confidence level. These businesses estimate VaR across their portfolio using a delta-normal variance/covariance model with a 95 percent confidence level and compare the measured VaR results against performance due to actual prices and stress test the portfolio each quarter using an assumed 30 percent price change from forecast. Since the VaR calculation involves complex methodologies and estimates and assumptions that are based on past experience, it is not necessarily indicative of future results. VaR for the portfolio, assuming a one-day holding period, for the six months ended June 30, 2017 and the year ended December 31, 2016, respectively, was as follows:

95% Confidence Level, One-Day Holding Period	June 30, 2017		December 31, 2016
	(Millions of Dollars)
Average for the period		$—	$2
High	1		4
Low	—		1

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Credit Risk

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. See the discussion of credit exposure in Note K to the Second Quarter Financial Statements.

Investment Risk

The Companies’ investment risk relates to the investment of plan assets for their pension and other postretirement benefit plans and to the investments of the Clean Energy Businesses and Con Edison Transmission that are accounted for under the equity method.

The Companies’ current investment policy for pension plan assets includes investment targets of 53 to 63 percent equities and 35 to 49 percent fixed income and other securities. At June 30, 2017, the pension plan investments consisted of 58 percent equity and 42 percent fixed income and other securities.

For the Utilities’ pension and other postretirement benefit plans, regulatory accounting treatment is generally applied in accordance with the accounting rules for regulated operations. In accordance with the Statement of Policy issued by the NYSPSC and its current electric, gas and steam rate plans, CECONY defers for payment to or recovery from customers the difference between the pension and other postretirement benefit expenses and the amounts for such expenses reflected in rates. Generally, O&R also defers such difference pursuant to its rate plans.

Material Contingencies

For information concerning potential liabilities arising from the Companies’ material contingencies, see "Other Regulatory Matters" in Note B and Notes G and H to the Second Quarter Financial Statements.

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Item 3: Quantitative and Qualitative Disclosures About Market Risk

For information about the Companies’ primary market risks associated with activities in derivative financial instruments, other financial instruments and derivative commodity instruments, see “Financial and Commodity Market Risks,” in Part I, Item 2 of this report, which information is incorporated herein by reference.

Item 4: Controls and Procedures

The Companies maintain disclosure controls and procedures designed to provide reasonable assurance that the information required to be disclosed in the reports that they submit to the Securities and Exchange Commission (SEC) is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Securities Exchange Act of 1934, as amended, is accumulated and communicated to the issuer’s management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. For each of the Companies, its management, with the participation of its principal executive officer and principal financial officer, has evaluated its disclosure controls and procedures as of the end of the period covered by this report and, based on such evaluation, has concluded that the controls and procedures are effective to provide such reasonable assurance. Reasonable assurance is not absolute assurance, however, and there can be no assurance that any design of controls or procedures would be effective under all potential future conditions, regardless of how remote.

There was no change in the Companies’ internal control over financial reporting that occurred during the Companies’ most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Companies’ internal control over financial reporting.

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Part II Other Information

Item 1: Legal Proceedings

For information about certain legal proceedings affecting the Companies, see "Other Regulatory Matters" in Note B and Notes G and H to the financial statements in Part I, Item 1 of this report and "Environmental Matters" in Part I, Item 2 of this report, which information is incorporated herein by reference.

Item 1A: Risk Factors

There were no material changes in the Companies’ risk factors compared to those disclosed in Item 1A of the Form 10-K.

Item 6: Exhibits

Con Edison

Exhibit 10.1	Amendment to the Severance Program for Officers of Consolidated Edison, Inc. and its Subsidiaries.
Exhibit 12.1	Statement of computation of Con Edison’s ratio of earnings to fixed charges for the six-month periods ended June 30, 2017 and 2016, and the 12-month period ended December 31, 2016.
Exhibit 31.1.1	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer.
Exhibit 31.1.2	Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer.
Exhibit 32.1.1	Section 1350 Certifications – Chief Executive Officer.
Exhibit 32.1.2	Section 1350 Certifications – Chief Financial Officer.
Exhibit 101.INS	XBRL Instance Document.
Exhibit 101.SCH	XBRL Taxonomy Extension Schema.
Exhibit 101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
Exhibit 101.DEF	XBRL Taxonomy Extension Definition Linkbase.
Exhibit 101.LAB	XBRL Taxonomy Extension Label Linkbase.
Exhibit 101.PRE	XBRL Taxonomy Extension Presentation Linkbase.

CECONY

Exhibit 4.2	Form of CECONY’s 3.875% Debentures, Series 2017 A (Designated in CECONY’s Edison's Current Report on Form 8-K, dated June 5, 2017 (File No. 1-1217) as Exhibit 4).
Exhibit 10.2	The Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan, as amended and restated effective January 1, 2017.
Exhibit 12.2	Statement of computation of CECONY’s ratio of earnings to fixed charges for the six-month periods ended June 30, 2017 and 2016, and the 12-month period ended December 31, 2016.
Exhibit 31.2.1	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer.
Exhibit 31.2.2	Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer.
Exhibit 32.2.1	Section 1350 Certifications – Chief Executive Officer.
Exhibit 32.2.2	Section 1350 Certifications – Chief Financial Officer.
Exhibit 101.INS	XBRL Instance Document.
Exhibit 101.SCH	XBRL Taxonomy Extension Schema.
Exhibit 101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
Exhibit 101.DEF	XBRL Taxonomy Extension Definition Linkbase.
Exhibit 101.LAB	XBRL Taxonomy Extension Label Linkbase.
Exhibit 101.PRE	XBRL Taxonomy Extension Presentation Linkbase.

Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, instruments defining the rights of holders of long-term debt of Con Edison’s subsidiaries other than CECONY, the total amount of which does not exceed ten percent of the total assets of Con Edison and its subsidiaries on a consolidated basis, are not filed as exhibits to Con Edison’s Form 10-K or Form 10-Q. Con Edison agrees to furnish to the SEC upon request a copy of any such instrument.

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Signatures

Pursuant to the requirements of the Securities Exchange Act of 1934, each Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	Consolidated Edison, Inc.
	Consolidated Edison Company of New York, Inc.
Date: August 3, 2017	By	/s/ Robert Hoglund
		Robert Hoglund Senior Vice President, Chief Financial Officer and Duly Authorized Officer

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EX-10.1

Exhibit 10.1

AMENDMENT THREE

TO THE

SEVERANCE PROGRAM FOR OFFICERS

OF

CONSOLIDATED EDISON, INC. AND ITS SUBSIDIARIES

(As Amended and Restated effective January 1, 2008)

In accordance with resolutions adopted by the Board of Directors of Consolidated Edison, Inc. and the Board of Trustees of Consolidated Edison Company of New York, Inc. on July 20, 2017 approving an amendment to the definition of “Participant” under the Severance Program for Officers of Consolidated Edison, Inc. and its Subsidiaries (the “Plan”), the undersigned hereby approves, effective as of January 1, 2017, the amendment to the Plan set forth below.

The definition of is“Participant” is amended as follows:

“Participant” at any time shall mean each person who (i) is an officer of CECONY, O&R, or CET, or is then holding the office of president or higher level of CEI or any subsidiary of CEI; provided, however, that any individual who would otherwise be a participant shall not be eligible to receive any severance payments or benefits hereunder (x) unless such individual has signed a release agreement with the Company in the form of Annex 1 hereto or in such form as has been approved by the Administrator for this purpose from time to time prior to a Change of Control, or (y) if such individual is a party to a then effective separate written agreement with the Company which has been authorized or adopted by the Board or the Committee which expressly provides for severance payments or benefits (unless such agreement expressly provides for participation in this Program).

IN WITNESS WHEREOF, the undersigned has executed this instrument this 24 day of July, 2017.

/s/ Richard Bagwell

Richard Bagwell

Plan Administrator, and Vice President -

Human Resources

Consolidated Edison Company of New York, Inc.

EX-12.1

Exhibit 12.1

Consolidated Edison, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Six Months Ended June 30, 2017	For The Twelve Months Ended December 31, 2016	For the Six Months Ended June 30, 2016
Earnings
Net Income	$563	$1,245	$542
Preferred Stock Dividend	—	—	—
(Income)/Loss from Equity Investees	(14)	(28)	(13	)
Minority Interest Loss	—	—	—
Income Tax	330	698	288
Pre-Tax Income	$879	$1,915	$817
Add: Fixed Charges*	377	730	366
Add: Distributed Income of Equity Investees	—	—	—
Subtract: Interest Capitalized	—	—	—
Subtract: Pre-Tax Preferred Stock Dividend Requirement	—	—	—
Earnings	$1,256	$2,645	$1,183
* Fixed Charges
Interest on Long-term Debt	$350	$664	$324
Amortization of Debt Discount, Premium and Expense	6	14	7
Interest Capitalized	—	—	—
Other Interest	7	24	12
Interest Component of Rentals	14	28	23
Pre-Tax Preferred Stock Dividend Requirement	—	—	—
Fixed Charges	$377	$730	$366
Ratio of Earnings to Fixed Charges	3.3	3.6	3.2

EX-31.1.1

Exhibit 31.1.1

CERTIFICATIONS

I, John McAvoy, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017 of Consolidated Edison, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2017

/s/ John McAvoy

John McAvoy

Chairman, President and Chief Executive Officer

EX-31.1.2

Exhibit 31.1.2

CERTIFICATIONS

I, Robert Hoglund, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017 of Consolidated Edison, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2017

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

EX-32.1.1

Exhibit 32.1.1

Certification Required Under Section 906 of the Sarbanes-Oxley Act of 2002

I, John McAvoy, the Chief Executive Officer of Consolidated Edison, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017, which this statement accompanies, (the “Form 10-Q”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)) and that the information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ John McAvoy

John McAvoy

Date: August 3, 2017

EX-32.1.2

Exhibit 32.1.2

Certification Required Under Section 906 of the Sarbanes-Oxley Act of 2002

I, Robert Hoglund, the Chief Financial Officer of Consolidated Edison, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017, which this statement accompanies, (the “Form 10-Q”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)) and that the information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Robert Hoglund

Robert Hoglund

Date: August 3, 2017

EX-10.2

Exhibit 10.2

CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

2005 EXECUTIVE INCENTIVE PLAN

Effective as of January 1, 2005

As Amended and Restated effective as of January 1, 2008

As Amended effective as of January 1, 2009

As amended effective as of January 1, 2010

As amended effective January 1, 2011

As amended effective January 1, 2015

As amended and restated effective January 1, 2017

Exhibit 10.2

CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

2005 EXECUTIVE INCENTIVE PLAN

PURPOSE

The purpose of the Plan is to provide executives designated by the Company’s Board of Trustees as eligible to participate in the Plan with incentives to achieve goals which are important to shareholders and customers of the Company, to supplement the Company’s salary and benefit programs so as to provide overall compensation for such executives which is more competitive with corporations with which the Company must compete for the best executive talent, and to assist the Company in attracting and retaining executives who are important to the continued success of the Company.

Effective January 1, 2006 the Plan was amended to add specific performance measures for the determination of the Adjusted Target Incentive Fund and the determination of the amount of any Incentive Award.

Effective January 1, 2007 the Plan is amended by adding new performance measures for the determination of the amount of the Incentive Award to be awarded to certain executives and to include the President and Chief Executive Officer of Orange and Rockland Utilities, Inc. and the Group President of the Competitive Energy Businesses as Participants in the Plan.

Effective January 1, 2008, the Plan is amended to permit Participants to defer up to one hundred percent (100%) of his or her Incentive Award into the Deferred Income Plan (as defined herein), subject to the terms and conditions of the Deferred Income Plan. Additionally, the Plan is further amended to add certain provisions in order to comply with the requirements of Section 409A of the Internal Revenue Code and the regulations and guidance promulgated thereunder.

Effective January 1, 2009, the Plan is amended to include the position of Executive Vice President as an Executive Officer.

Effective January 1, 2010, the Plan is amended to increase the percentage range of the three performance measurement in the calculation of the Target Incentive Fund and the percentage range for the payment of Incentive Awards.

Effective January 1, 2011, the Plan is amended to change the performance indicators the Board of Trustees considers in determining the Adjusted Target Incentive Fund by adding a capital budget performance indicator with a 10 percent weight, reducing the weight of the operating budget performance indicator from 20 percent to 10 percent, and adding productivity measures to both the capital and operating budget results.

Effective January 1, 2011, the Plan is amended to include language specifically stating that any Award granted to an Officer based on a performance period beginning on or after January 1, 2011 is subject to the Company’s Recoupment Policy, as amended from time to time.

Effective January 1, 2015, the Plan is amended to (i) include the following titles as eligible employees under the Plan, any Vice President of Orange and Rockland Utilities Inc., Senior Vice President - Corporate Shared Services and Senior Vice President - Utility Shared Services and (ii) reduce the maximum Incentive Award that may be payable under the Plan from 200% to 192.5%.

Exhibit 10.2

Effective January 1, 2017, the Plan is amended to (i) include the title of President and Chief Executive Officer of Con Edison Transmissions, Inc. as an eligible employee under the Plan, (ii) change the weightings of the performance indicators that the Board of Trustees considers in determining the Adjusted Target Incentive Fund and (iii) increase the maximum Incentive Award that may be payable under the Plan from 192.5% to 195%.

Exhibit 10.2

TABLE OF CONTENTS

Page

ARTICLE I. DEFINITIONS 1

1.01 Adjusted Target Incentive Fund                            1

shall have the meaning set forth in Section 4.03(c). 1

1.02 Annual Incentive Awards                                1

1.03 AIP                                            1

1.04 ATIP                                            1

1.05 Award Date                                        1

1.06 Board of Trustees                                    1

1.07 Board of Directors                                    1

1.08 Capital Budget                                    1

1.09 CEBs                                            1

1.10 CECONY Net Income                                1

1.11 CEI                                            2

1.12 CEI Net Income                                    2

1.13 CET                                            2

1.14 Committee                                        2

1.15 Company or CECONY                                2

1.16 Deferred Income Plan or DIP                            2

1.17 Effective Date                                    2

shall mean January 1, 2005. 2

1.18 Executive Officer                                    2

1.19 Financial Performance                                3

1.20 Incentive Award                                    3

1.21 Incentive Percentage                                3

shall have the meaning set forth in Section 4.01. 3

1.22 Officer                                            3

1.23 Operating Budget                                    3

1.24 Operating Performance                                3

1.25 O&R                                            3

1.26 O&R Net Income                                    3

1.27 Participant                                        3

1.28 Performance Indicators                                3

1.29 Plan                                            4

1.30 Plan Administrator                                    4

1.31 Potential Award                                    4

1.32 Regulated Net Income                                4

1.33 Senior Officer                                    4

1.34 Target Incentive Fund                                4

shall have the meaning set forth in Section 4.02(a). 4

Exhibit 10.2

ARTICLE II. ELIGIBILITY 4

2.01 4

2.02 4

2.03 4

ARTICLE III. ADMINISTRATION 5

3.01 5

ARTICLE IV. DETERMINATION OF AWARDS 5

4.01 Incentive Percentages                                5

4.02 Target Incentive Fund                                5

4.03 Adjusted Target Incentive Fund                            6

4.04 Incentive Awards                                    7

4.05 Awards to Executive Officers                         8

ARTICLE V. PAYMENT OF AWARDS 12

5.01 Time of Payment                                 12

5.02 Manner of Payment                                 12

5.03 Posthumous Payments                             12

5.04 Recoupment of Awards                             13

ARTICLE VI. MISCELLANEOUS 13

6.01 Amendment and Termination                         13

6.02 Effect of Plan                                     13

6.03 Withholding                                     13

6.04 Funding                                     14

6.05 Facility of Payment                             14

6.06 Nonalienation                                 14

Exhibit 10.2

CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

2005 EXECUTIVE INCENTIVE PLAN

ARTICLE I. DEFINITIONS

The following terms when capitalized herein shall have the meanings set forth below.

1.01    Adjusted Target Incentive Fund

shall have the meaning set forth in Section 4.03(c).

1.02    Annual Incentive Awards

shall mean annual awards made under the terms of this Plan, the AIP, the ATIP, the CEI Annual Incentive Plan, the Annual Executive Incentive Plan for Presidents of the Consolidated Edison, Inc. Competitive Energy Businesses, and the Management Variable Pay Plan for CECONY management employees.

1.03    AIP

shall mean the Con Edison Competitive Energy Businesses Annual Incentive Plan, as may be amended from time to time, or may mean, effective January 1, 2017, the Con Energy Transmission, Inc. (“CET”) Annual Incentive Award, as set forth in Section 4.05 herein.

1.04    ATIP

shall mean the O&R Annual Team Incentive Plan, as may be amended from time to time.

1.05    Award Date

shall mean, with respect to any Incentive Award, January 1 of the year following the year to which such Incentive Award relates.

1.06    Board of Trustees

shall mean the Board of Trustees of the Company or the Management Development and Compensation Committee of the Board of Trustees, if the Board has given the Committee authority to act on its behalf.

1.07    Board of Directors

shall mean the Board of Directors of Consolidated Edison, Inc or the Management Development and Compensation Committee of the Board of Directors, if the Board of Directors has given the Committee authority to act on its behalf.

1.08    Capital Budget

shall mean the portion of the CECONY Capital Budget approved by the Board of Trustees that is comprised of capital expenditures, including electric, gas, steam, and common. The Capital Budget goal may exclude certain expenditures as determined and approved by the Board of Trustees.

1.09    CEBs

shall mean the Competitive Energy Businesses.

1.10    CECONY Net Income

shall mean net income from ongoing operations for CECONY, which includes income from CECONY operations after subtracting all expenses incurred by CECONY, including federal

1

Exhibit 10.2

and state income taxes. Net income shall not include extraordinary non-recurring items identified by the Company after the target is established. Net income shall be net of the reserve that is established for the Target Incentive Fund and awards made under the Management Variable pay plan during the year-end closing and shall not be weather normalized.

1.11    CEI

shall mean Consolidated Edison, Inc., or any successor by merger, purchase or otherwise.

1.12    CEI Net Income

shall mean net income from ongoing operations for CEI which includes income from CEI operations after subtracting all expenses incurred by CEI, including federal and state income taxes. CEI Net Income shall not include extraordinary non-recurring items identified by the Company after the target is established or the impacts of mark-to-market activity. CEI Net income shall be net of the reserve that is established for the Annual Incentive Awards during the year-end closing.

1.13    CET

shall mean Con Energy Transmission, Inc.

1.14    Committee

shall mean The Management Development and Compensation Committee of the Board of Directors or the Management Development and Compensation Committee of the Board of Trustees, as applicable.

1.15    Company or CECONY

shall mean Consolidated Edison Company of New York, Inc. or any successor by merger, purchase or otherwise.

1.16    Deferred Income Plan or DIP

shall mean the Consolidated Edison Company of New York, Inc. Deferred Income Plan, as amended from time to time.

1.17    Effective Date

shall mean January 1, 2005.

1.18    Executive Officer

shall mean an executive of the Company who holds the position of Chairman and Chief Executive Officer, Executive Vice President, Senior Vice President and Chief Financial Officer, General Counsel, President and Chief Operating Officer, Senior Vice President - Business Shared Services, Senior Vice President - Enterprise Shared Services, Senior Vice President - Public Affairs, or Vice President and General Auditor; an executive of Orange and Rockland Utilities Inc. who holds the title of President and Chief Executive Officer; or an executive of CEI who holds the title of The Group President, Competitive Energy Businesses.

Effective January 1, 2015, the above definition is amended to include any Vice President of Orange and Rockland Utilities Inc. The positions “Senior Vice President - Corporate Shared Services” and “Senior Vice President - Utility Shared Services” are added. All other positions

2

Exhibit 10.2

under this Section 1.17 remain the same. Effective January 1, 2017, “Executive Officer” shall include the President and Chief Executive Officer of Con Edison Transmission, Inc.

1.19    Financial Performance

shall mean the financial performance component used to determine an Executive Officer’s Target Award and shall be either the same as the component used for determining awards under Section 4.04 of this Plan, the ATIP, the AIP, or a combination thereof as applicable to the Executive Officer and as set forth in Section 4.05.

1.20    Incentive Award

shall have the meaning set forth in Section 4.04 or Section 4.05, as applicable.

1.21    Incentive Percentage

shall have the meaning set forth in Section 4.01.

1.22    Officer

shall mean an executive of CECONY who is not a Senior Officer or an Executive Officer.

1.23    Operating Budget

shall mean the portion of the CECONY O & M Budget approved by the Board of Trustees which is comprised of departmental expenses, including Interference and Uncollectible expenses. Operating Budget shall not include corporate expenses such as employee benefits, damages and lawsuits, rental fees (transformer vault rental) and external audit fees.

1.24    Operating Performance

shall mean the operating performance component used to determine an Executive Officer’s Target Award and shall be either the same as the component used for determining awards under Section 4.04 of this Plan, the ATIP, the AIP, or a combination thereof as applicable to the Executive Officer and as set forth in Section 4.05.

1.25    O&R

shall mean Orange and Rockland Utilities, Inc.

1.26    O&R Net Income

shall mean net income from ongoing operations for O&R, which includes income from O&R operations after subtracting all expenses incurred by O&R, including federal and state income taxes. Net income shall not include extraordinary non-recurring items identified by O&R after the target is established. Net income shall be net of the reserve that is established for the Target Incentive Fund and the ATIP awards during the year-end closing and shall not be weather normalized.

1.27    Participant

shall mean any individual who is eligible to participate in the Plan in accordance with Article II.

1.28    Performance Indicators

shall mean health and safety, operational considerations, customer satisfaction, reliability, environmental considerations, employee development considerations or any other or additional performance indicators that the Board of Trustees may, from time to time, deem appropriate.

3

Exhibit 10.2

1.29    Plan

shall mean the Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan, as amended.

1.30    Plan Administrator

shall mean the individual appointed by the Company’s Chief Executive Officer to administer the Plan as provided in Article III.

1.31    Potential Award

shall have the meaning set forth in Section 4.02(c).

1.32    Regulated Net Income

shall mean the total of CECONY Net Income and O&R Net Income.

1.32    Senior Officer

shall mean a Senior Vice President of CECONY who is not an Executive Officer.

1.34    Target Incentive Fund

shall have the meaning set forth in Section 4.02(a).

ARTICLE II. ELIGIBILITY

2.01     The Board of Trustees, in its discretion, from time to time, may designate and change the designation of the executives or executive position levels within the Company eligible to participate in the Plan. The Board of Directors, in its discretion, from time to time, may designate the Executive Officers eligible to participate in the Plan.

2.02    To be eligible to receive an award under the Plan for a particular year, an executive (other than an Executive Officer) must (a) have been employed by the Company during any portion of such year and (b) not later than September 30 of such year achieve an eligible position level or be designated by the Board of Trustees as eligible to participate in the Plan. To be eligible to receive an award under the Plan for a particular year, an Executive Officer, must (x) have been employed by the Company, CEI or O&R during any portion of such year and (y) not later than September 30 of such year achieve an Executive Officer position or be designated by the Board of Directors as eligible to participate in the Plan.

2.03    If a Participant retires or resigns after June 30 at age 55 with at least five years of service, he or she may, in the sole discretion of the Plan Administrator, receive a prorated Incentive Award based on the number of calendar months worked during the year to which such Incentive Award relates.

4

Exhibit 10.2

ARTICLE III. ADMINISTRATIONADMINISTRATION

3.01    Except as otherwise provided in the Plan, all determinations in connection with the Plan shall be made by the Plan Administrator, who shall be appointed by the Company’s Chief Executive Officer and whose decisions shall be final and conclusive upon all Participants and any persons asserting any claim derived from a Participant. The Plan Administrator shall make such determinations after receiving the recommendations of the Company’s Chief Executive Officer (except as to matters relating to the participation of the Company’s Chief Executive Officer in the Plan and decisions with respect to him or her shall be made by the Board of Trustees). The Plan Administrator shall abstain from any determination under the Plan in which he or she has a personal interest, in which case such determination shall be made by the Company’s Chief Executive Officer. The Plan Administrator shall be responsible for the administration of the Plan under the direction of the Company’s Chief Executive Officer.

ARTICLE IV. DETERMINATION OF AWARDS

4.01    Incentive Percentages

Except as provided in Section 4.05, the Board of Trustees shall determine a percentage of annual salary deemed to constitute an appropriate incentive for each executive or executive position level eligible to participate in the Plan. Each such percentage is herein called an “Incentive Percentage”. The Board of Trustees may, from time to time, increase or decrease any Incentive Percentage, as the Board of Trustees may deem appropriate.

4.02    Target Incentive Fund

Except as provided in Section 4.05:

(a)At the end of each year, the annual rate of salary of each executive eligible to participate in the Plan for such year, as such salary is in effect at the end of such year, shall be multiplied by the Incentive Percentage applicable to such person at such time. The sum of such products for all executives eligible to participate in the Plan for such year is herein called the “Target Incentive Fund” for such year.

(b)For purposes of calculating the Target Incentive Fund for any year:

(1)In the case of an executive whose employment with the Company has terminated during the year, the annual salary rate of such executive in effect at the time of such termination shall be deemed to be the annual salary rate of such executive at the end of such year.

(2)Deferred compensation, at the annual rate in effect at the end of the year pursuant to an agreement between the Company and an executive, shall be considered part of such executive’s annual rate of salary at the end of such year.

(3)An executive’s annual rate of salary shall be determined without any deduction for pre-tax contributions or after-tax contributions made pursuant to the Consolidated Edison Thrift Savings Plan, the Con Edison Flexible Reimbursement Account Plan, the Con Edison OPTIONS Program for Management Employees, or the Deferred Income Plan.

5

Exhibit 10.2

(c)The amount included in the Target Incentive Fund for any year with respect to each executive is called such executive’s “Potential Award”.

4.03    Adjusted Target Incentive Fund

Except as provided in Section 4.05:

(a)Each year the Board of Trustees shall determine whether award of the Target Incentive Fund for the preceding year is appropriate or whether and to what extent such Target Incentive Fund shall be reduced, eliminated entirely, or increased. The Board of Trustees may increase or decrease the Target Incentive Fund.

(i)Effective Prior to January 1, 2011. In making such determination, the Board of Trustees shall consider the Company’s performance during the preceding year with respect to pre-determined goals in the following three areas: 1) CECONY Net Income, 2) the CECONY Operating Budget, and 3) specific Performance Indicators. The weighting assigned to each of these three areas will be as follows: Fifty percent (50%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the CECONY Net Income goal; Twenty percent (20%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the CECONY Operating Budget goal, and thirty percentage (30%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the Performance Indicators goal. The actual percentage in each of these three areas that shall comprise the Target Incentive Fund can range from zero to One Hundred Twenty percent (120%) of the respective areas’ weight based on the actual outcomes with respect to the goal for those areas as determined by the Board of Trustees. Effective January 1, 2010, the actual percentage in each of these three areas that shall comprise the Target Incentive Fund can range from zero to two hundred percent (200%) of the respective areas’ weight based on the actual outcomes with respect to the goal for those areas as determined by the Board of Trustees. The Board of Trustees may consider such additional Performance Indicators as the Board of Trustees deems relevant.

(ii)Effective January 1, 2011. In making such determination, the Board of Trustees shall consider the Company’s performance during the preceding year with respect to pre-determined goals in the following four areas: 1) CECONY Net Income; 2) the CECONY Operating Budget; 3) the CECONY Capital Budget; and 4) specific Performance Indicators. The weighting assigned to each of these four areas will be as follows: Fifty percent (50%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the CECONY Net Income goal; Ten percent (10%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the CECONY Operating Budget goal, Ten percent (10%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the CECONY Capital Budget goal, and thirty percent (30%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the Performance Indicators goal. The results for the CECONY Operating Budget and the CECONY Capital Budget will be modified based on the achievement of certain productivity measures as determined and approved by the Board of Trustee. The actual percentage in each of these four areas that shall comprise the Target Incentive Fund can range from zero to two hundred percent (200%) of the respective areas’ weight based on the actual outcomes with respect to the goal for those areas as determined by the Board of Trustees. The Board of Trustees may consider such additional Performance Indicators as the Board of Trustees deems relevant.

6

Exhibit 10.2

(iii)Effective January 1, 2017, In making such determination, the Board of Trustees shall consider the Company’s performance during the preceding year with respect to pre-determined goals in the following four areas: 1) CECONY Net Income; 2) the CECONY Operating Budget; 3) the CECONY Capital Budget; and 4) specific Performance Indicators. The weighting assigned to each of these four areas will be as follows: Fifty percent (50%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the CECONY Net Income goal; fifteen percent (15%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the CECONY Operating Budget goal, Ten percent (10%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the CECONY Capital Budget goal, and twenty five percent (25%) of the Target Incentive Fund shall be based on the Company’s performance with respect to the Performance Indicators goal. The results for the CECONY Operating Budget and the CECONY Capital Budget will be modified based on the achievement of certain productivity measures as determined and approved by the Board of Trustee. The actual percentage in each of these four areas that shall comprise the Target Incentive Fund can range from zero to two hundred percent (200%) of the respective areas’ weight based on the actual outcomes with respect to the Adjusted Net Income, Operating Budget, and operational performance. A sliding scale from zero to one hundred twenty percent (120%) will be applied to the CECONY Capital Budget component based on actual results. The Board of Trustees may consider such additional Performance Indicators as the Board of Trustees deems relevant.

(b)Notwithstanding any other provision, the Target Incentive Fund for any year in which the Company omits a dividend on its common stock, or in which the CECONY Net Income is less than ninety percent (90%) of its target, shall be reduced to zero.

(c)The Target Incentive Fund for a year, as adjusted pursuant to this Section 4.03, is herein called the “Adjusted Target Incentive Fund”.

4.04    Incentive Awards

Except as provided in Section 4.05:

(a)After the Adjusted Target Incentive Fund for a year has been determined as provided in Section 4.03, the Committee of the Board of Trustees, upon the recommendations of the Company’s Chief Executive Officer, shall make, subject to confirmation by the Board of Trustees, awards to individual Participants who are eligible to participate in the Plan based on the achievement of Company performance goals, organizational performance, and the Participant’s individual performance for such year. Such awards are herein called “Incentive Awards”.

(1)Incentive Awards shall be determined based on the following criteria:

(i)For each Senior Officer, his or her Incentive Award shall be based on the following four components weighted as indicated: fifteen percent (15%) shall be based on the Company achieving its CECONY Net Income goal; twenty percent (20%) shall be based on his or her organization achieving its budget goal; twenty-five percent

7

Exhibit 10.2

(25%) shall be based on his or her organization achieving its Performance Indicators, and forty percent (40%) shall be based on his or her individual performance.

(ii)For all other Participants, except Senior Officers, his or her Incentive Award shall be based on the following four components weighted as indicated: twelve and one-half percent (12.5%) shall be based on the Company achieving its CECONY Net Income goal, seventeen and one-half percent (17.5%) shall be based on his or her Group achieving its budget goal; thirty percent (30%) shall be based on his or her Group achieving its Performance Indicators, and forty percent (40%) shall be based on his or her individual performance.

(iii)(a)Effective Prior to January 1, 2010. The actual percentage of the Incentive Award based on the individual performance component may range from zero to one hundred fifty percent (150%) based on the Participant’s actual performance. The actual percentage of the Incentive Award based on the remaining three components may range from zero to one hundred twenty percent (100%) based on the actual outcomes with respect to the goals for those components. As a result, a Participants actual Incentive Award may range from zero to one hundred thirty two percent (132%) of the Participant’s Potential Award.

(b)Effective January 1, 2010. The actual percentage of the Incentive Award based on the individual performance component may range from zero to one hundred fifty percent (150%) based on the Participant’s actual performance. The actual percentage of the Incentive Award based on the remaining three components may range from zero to one hundred (100%) based on the actual outcomes with respect to the goals for those components. As a result of the increase in the maximum range of the Target Incentive Fund effective January 1, 2010, a Participant’s actual Incentive Award may range from zero to two hundred forty percent (240%) of the Participant’s Potential Award.

(b)If, however, a Participant has entered into an employment agreement with the Company providing for a different basis for the determination of his or her Incentive Award under this Plan, the determination of the amount of his or her Incentive Award will be governed by the terms and conditions set forth in his or her employment agreement.

(c)The aggregate of all Incentive Awards for a year may not exceed the Adjusted Target Incentive Fund for such year.

4.05    Awards to Executive Officers

Notwithstanding the foregoing, the determination of the Incentive Award for an Executive Officer shall be in accordance with this Section 4.05 instead of Sections 4.01, 4.02, 4.03 and 4.04.

(a)The Incentive Award of an Executive Officer shall be determined based on the following criteria:

(1)The Board of Directors shall determine the Incentive Percentage for each Executive Officer eligible to participate in the Plan. The Board of Directors may, from time to time, increase or decrease any Executive Officer’s Incentive Percentage, as it may deem appropriate.

8

Exhibit 10.2

(2)Each Executive Officer’s Incentive Award will be based on three components: net income, Financial Performance and Operating Performance.

(b)For the Chairman and Chief Executive Officer, Executive Vice President, Senior Vice President and Chief Financial Officer, and General Counsel.

(1)The net income component will constitute fifty percent (50%) of the Incentive Award and the measure will be CEI Net Income.

(2)The Financial Performance component will constitute twenty percent (20%) of the Incentive Award and the component will be established in January of each Plan year by the Board of Trustees for EIP awards, by the Board of Directors of O&R for ATIP awards and the Board of Directors of the CEBs and CET, for their respective AIP awards. The weighting applied to this component will be based on the budgeted net income of CECONY, O&R, the CEBs, and effective January 1, 2017, CET for such year. Effective January 1, 2017, the Financial Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(3)The Operating Performance component will constitute thirty percent (30%) of the Incentive Award and the component will be established in January of each year by the Board of Trustees for EIP awards, the Board of Directors of O&R for ATIP awards and the Board of Directors of the CEBs and CET for their respective AIP awards. The weighting applied to this component will be based on the budgeted net income of CECONY, O&R, the CEBs and effective January 1, 2017, CET for such year. Effective January 1, 2017, the Operating Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(c)For the President and Chief Executive Officer of O&R.

(1)The net income component will constitute fifty percent (50%) of the Incentive Award and the measure will be Regulated Net Income and will be weighted 80% on the O&R Adjusted Net Income Payout percentage achieved plus 20% on the CECONY Adjusted Net Income Payment percentage achieved.

(2)The Financial Performance component will constitute twenty percent (20%) of the Incentive Award and the component will be the same as the component established in January of each year by the Board of Directors of O&R for the ATIP awards. Effective January 1, 2017, the Financial Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(3)The Operating Performance component will constitute thirty percent (30%) of the Incentive Award and the component will be the same as the component established in January of each year by the Board of Directors of O&R for the ATIP awards. Effective January 1, 2017, the Operating Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(d)For the Group President, Competitive Energy Businesses.

9

Exhibit 10.2

(1)The net income component will constitute fifty percent (50%) of the Incentive Award and the measure will be CEI Net Income.

(2)The Financial Performance component will constitute twenty percent (20%) of the Incentive Award and the component will be the same as the component established in January of each year by the Board of Directors of the CEBs for the AIP awards.

(3)The Operating Performance component will constitute thirty percent (30%) of the Incentive Award and the component will be the same as the component established in January of each year by the Board of Directors of the CEBs for the AIP awards.

(e)For the President and Chief Operating Officer of CECONY.

(1)The net income component will constitute fifty percent (50%) of the Incentive Award and the measure will be Regulated Net Income.

(2)The Financial Performance component will constitute twenty percent (20%) of the Incentive Award and the component will be the same as the component established in January of each year by the Board of Trustees for the EIP awards. Effective January 1, 2017, the Financial Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(3)The Operating Performance component will constitute thirty percent (30%) of the Incentive Award and the component will be the same as the component established in January of each year by the Board of Trustees for the EIP awards. Effective January 1, 2017, the Operating Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(f)For the Senior Vice President - Business Shared Services, Senior Vice President - Enterprise Shared Services, Senior Vice President - Corporate Shared Services, Senior Vice President - Utility Shared Services, Senior Vice President - Public Affairs, Vice President and General Auditor.

(1) The net income component will constitute fifty percent (50%) of the Incentive Award and the measure will be Regulated Net Income.

(2) The Financial Performance component will constitute twenty percent (20%) of the Incentive Award and the component will be the same as the component established in January of each year by the Board of Trustees for the EIP awards and by the Board of Directors of O&R for the ATIP awards. The weighting applied to these this component will be based on the budgeted net income at CECONY and O&R for such year. Effective January 1, 2017, the Financial Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(3) The Operating Performance component will constitute thirty percent (30%) of the Incentive Award and the component will be the same as the component established in January of each year by the Board of Trustees for the EIP awards and by the Board of Directors of for the ATIP awards. The weighting applied

10

Exhibit 10.2

to this component will be based on the budgeted net income at CECONY and O&R for such year. Effective January 1, 2017, the Operating Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(g)For the Vice Presidents of O&R.

(1) The net income component will constitute fifty percent (50%) of the Incentive Award and the measure will be the O&R Adjusted Net Income Payout percentage achieved.

(2) The Financial Performance component will constitute twenty percent (20%) of the Incentive Award and the component will be the same as the component established in the first quarter of each year by the Board of Directors of O&R for the ATIP awards. Effective January 1, 2017, the Financial Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(3) The Operating Performance component will constitute thirty percent (30%) of the Incentive Award and the component will be the same as the component established in the first quarter of each year by the Board of Directors of O&R for the ATIP awards. Effective January 1, 2017, the Operating Performance component shall constitute twenty five percent (25%) of the Incentive Award.

(h) For the President and Chief Executive Officer of Con Edison Transmission, Inc.

(1)The net income component will constitute fifty percent (50%) of the Incentive Award and will be weighted 60% on the CET Adjusted Net Income Payment percentage achieved, plus 20% on the CEI Adjusted Net Income Payment percentage achieved, and 20% on the CEB Adjusted Net Income Payment percentage achieved.

(2)The Financial Performance component will constitute twenty five percent (25%) of the Incentive Award and will be weighted 60% on the CET operating budget and 40% on the CEB operating budget.

(3)The Operating Performance component will constitute twenty five percent (25%) of the Incentive Award and will be weighted 60% on the CET operational performance and 40% on the CEB operational performance.

(i)(1)Effective Prior to January 1, 2010. The actual Incentive Award for an Executive Officer may range from zero to one hundred twenty percent (120%) of the target award (i.e., a percentage of the Executive Officer’s year-end salary equal to his or her Incentive Percentage) based on the annual performance with respect to the applicable net income, Financial Performance and Operating Performance components for the Executive Officer described above.

(2)Effective January 1, 2010. The actual Incentive Award for an Executive Officer may range from zero to two hundred (200%) of the target award (i.e., a percentage of the Executive Officer’s year-end salary equal to his or her Incentive Percentage) based on the

11

Exhibit 10.2

annual performance with respect to the applicable net income, Financial Performance and Operating Performance components for the Executive Officer described above.

(3) Effective January 1, 2015. The actual Incentive Award for an Executive Officer may range from zero to one hundred ninety two and one half percent (192.5%) of the target award (i.e., a percentage of the Executive Officer’s year-end salary equal to his or her Incentive Percentage) based on the annual performance with respect to the applicable net income, Financial Performance and Operating Performance components for the Executive Officer described above.

(4) Effective January 1, 2017. The actual Incentive Award for an Executive Officer may range from zero to one hundred ninety five (195%) of the target award (i.e., a percentage of the Executive Officer’s year-end salary equal to his or her Incentive Percentage) based on the annual performance with respect to the applicable net income, Financial Performance and Operating Performance components for the Executive Officer described above.

(j)Each Executive Officer’s Incentive Award payout will be determined based upon the satisfaction of the applicable performance goals. The Committee of the Board of Directors, however, has the discretion to adjust an Executive Officer’s Incentive Award based on a review of the performance of the Company, CEI, O&R, or a combination thereof, including financial, operating and other factors, and based upon the recommendation of the Company’s Chairman and Chief Executive Officer (except with respect to his own award). The Committee of the Board of Directors shall make, subject to confirmation by the Board of Directors, the Incentive Award to the individual Executive Officer.

(k)If, however, the Executive Officer has entered into an employment agreement with the Company, CEI or O&R providing for a different basis for the determination of his or her Incentive Award under this Plan, the determination of the amount of his or her Incentive Award will be governed by the terms and conditions set forth in his or her employment agreement.

ARTICLE V. PAYMENT OF AWARDS

5.01    Time of Payment

An Incentive Award shall be paid between January 1 and March 15 of the year following the year to which such Incentive Award relates. Participants may defer up to two-thirds of their Incentive Award into the DIP upon the terms and conditions as set forth in the DIP. Effective January 1, 2008, a Participant may defer up to 100 percent of his or her Incentive Award into the DIP upon the terms and conditions as set forth in the DIP, less any applicable withholding taxes required to be withheld pursuant to Section 6.03.

5.02    Manner of Payment

Any portion of the Incentive Award that is not deferred under the terms of the DIP shall be paid to the Participant in a single lump sum.

5.03    Posthumous Payments

12

Exhibit 10.2

If a Participant shall die before any payment to be made to the Participant under this Plan has been made, the payment shall be made to the Participant’s estate or personal representative in a single lump sum in accordance with Section 5.01.

5.04    Recoupment of Awards

The Participant’s Incentive Award, is subject to the Company’s Recoupment Policy, as amended from time to time.

(a) Under this Recoupment Policy, appropriate actions, as determined by the Committee, will be undertaken by the Company to recoup the Excess Award Amount, as defined below, received by any Participant when:

(1)The Audit Committee of CEI determines that CEI is required to prepare an accounting restatement due to its material noncompliance with any financial reporting requirement under the securities laws ( a “Restatement”);

(2)The Participant received an Award during the three-year period preceding the date on which CEI is required to prepare a Restatement; and

(3)The amount of the Award received by the Participant, based on the erroneous data, was in excess of what would have been paid to the Participant under the Restatement (the “Excess Award Amount”).

ARTICLE VI. MISCELLANEOUS

6.01    Amendment and Termination

The Company reserves the right, by action of the Board of Trustees, to terminate the Plan entirely, or to temporarily or permanently discontinue the making of awards under the Plan; and further reserves the right, by action of the Board of Trustees or the Plan Administrator, to otherwise modify the Plan from time to time; provided that no such modification, termination, or discontinuance shall adversely affect the rights of Participants with respect to Incentive Awards previously determined; and provided further, that no modification by action of the Plan Administrator shall have a material effect on the benefits payable under the Plan.

6.02    Effect of Plan

The establishment and continuance of the Plan shall not constitute a contract of employment between the Company and any employee. No person shall have any claim to be granted an award under the Plan and there is no obligation for uniformity of treatment of employees or Participants under the Plan. Neither the Plan nor any action taken under the Plan shall be construed as giving to any employees the right to be retained in the employ of the Company, nor any right to examine the books of the Company, or to require an accounting.

6.03    Withholding

The Company shall deduct from any payment under the Plan any federal, state, or local income or employment taxes that the Company, in its sole discretion, determines is required

13

Exhibit 10.2

by law or governmental rule or regulation to be withheld with respect to such payment. Each Participant shall bear all expenses of, and be solely responsible for all federal, state and local taxes due with respect to any payment received under this Plan. All payments will be reported to the IRS.

6.04    Funding

All amounts payable in accordance with this Plan shall constitute a general unsecured obligation of the Company. Such amounts, as well as any administrative costs relating to the Plan, shall be paid out of the general assets of the Company.

6.05    Facility of Payment

In the event that the Plan Administrator shall find that a Participant is unable to care for such Participant’s affairs because of illness or accident, the Plan Administrator may, unless claim shall have been made therefore by a duly appointed legal representative, direct that any benefit payment due the Participant, to the extent not payable from a grantor trust, be paid on the Participant’s behalf to the Participant’s spouse, a child, a parent or other blood relative, or to a person with whom the Participant resides or a legal guardian, and any such payment so made shall be a complete discharge of the liabilities of the Company and the Plan therefore. Such payment shall be made in accordance with the terms and conditions set forth in Article V.

6.06    Nonalienation

Subject to any applicable law, no benefit under the Plan shall be subject in any manner to anticipation, alienation, sale, transfer, assignment, pledge, encumbrance or charge, and any attempt to do so shall be void, nor shall any such benefit be in any manner liable for or subject to garnishment, attachment, execution or levy, or liable for or subject to the debts, contracts, liabilities, engagements or torts of the person entitled to such benefits.

Pursuant to resolutions of the Management Development and Compensation Committees of the Board of Directors of Consolidated Edison, Inc., and Consolidated Edison Company of New York, Inc. adopted on February 15, 2017, and the authority granted to the Plan Administrator under section 6.01 of the Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan, the undersigned hereby approves the Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan, as amended and restated herein.

14

Exhibit 10.2

IN WITNESS WHEREOF, the undersigned has executed the instrument this day of July 14, 2017

/s/ Richard Bagwell

Richard Bagwell

Plan Administrator

Consolidated Edison Company of New York, Inc.

2005 Executive Incentive Plan, and

Vice President-Human Resources

Consolidated Edison Company of New York, Inc.

15

EX-12.2

Exhibit 12.2

Consolidated Edison Company of New York, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Six Months Ended June 30, 2017	For the Twelve Months Ended December 31, 2016	For the Six Months Ended June 30, 2016
Earnings
Net Income	$482	$1,056	$472
Preferred Stock Dividend	—	—	—
(Income)/Loss from Equity Investees	—	—	—
Minority Interest Loss	—	—	—
Income Tax	309	603	264
Pre-Tax Income	$791	$1,659	$736
Add: Fixed Charges*	323	634	321
Add: Distributed Income of Equity Investees	—	—	—
Subtract: Interest Capitalized	—	—	—
Subtract: Pre-Tax Preferred Stock Dividend Requirement	—	—	—
Earnings	$1,114	$2,293	$1,057
* Fixed Charges
Interest on Long-term Debt	$295	$575	$283
Amortization of Debt Discount, Premium and Expense	6	13	7
Interest Capitalized	—	—	—
Other Interest	8	19	9
Interest Component of Rentals	14	27	22
Pre-Tax Preferred Stock Dividend Requirement	—	—	—
Fixed Charges	$323	$634	$321
Ratio of Earnings to Fixed Charges	3.4	3.6	3.3

EX-31.2.1

Exhibit 31.2.1

CERTIFICATIONS

I, John McAvoy, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017 of Consolidated Edison Company of New York, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2017

/s/ John McAvoy

John McAvoy

Chairman and Chief Executive Officer

EX-31.2.2

Exhibit 31.2.2

CERTIFICATIONS

I, Robert Hoglund, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017 of Consolidated Edison Company of New York, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2017

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

EX-32.2.1

Exhibit 32.2.1

Certification Required Under Section 906 of the Sarbanes-Oxley Act of 2002

I, John McAvoy, the Chief Executive Officer of Consolidated Edison Company of New York, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017, which this statement accompanies, (the “Form 10-Q”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)) and that the information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ John McAvoy

John McAvoy

Date: August 3, 2017

EX-32.2.2

Exhibit 32.2.2

Certification Required Under Section 906 of the Sarbanes-Oxley Act of 2002

I, Robert Hoglund, the Chief Financial Officer of Consolidated Edison Company of New York, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017, which this statement accompanies, (the “Form 10-Q”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)) and that the information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Robert Hoglund

Robert Hoglund

Date: August 3, 2017

XML

Document and Entity Information - shares	6 Months Ended
	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

XML

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

XML

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

XML

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

XML

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

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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

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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)

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General

6 Months Ended

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).

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Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2017

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

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.

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Regulatory Matters

6 Months Ended

Jun. 30, 2017

Regulated Operations [Abstract]

Regulatory Matters

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

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Capitalization

6 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

Capitalization

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.

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Short-Term Borrowing

6 Months Ended

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.

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Pension Benefits

6 Months Ended

Jun. 30, 2017

Retirement Benefits [Abstract]

Pension Benefits

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.

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Other Postretirement Benefits

6 Months Ended

Jun. 30, 2017

Retirement Benefits [Abstract]

Other Postretirement Benefits

Other Postretirement Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic other postretirement benefit costs for the three and 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.

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Environmental Matters

6 Months Ended

Jun. 30, 2017

Environmental Remediation Obligations [Abstract]

Environmental Matters

Environmental Matters

Superfund Sites

Hazardous substances, such as asbestos, polychlorinated biphenyls (PCBs) and coal tar, have been used or generated in the course of operations of the Utilities and their predecessors and are present at sites and in facilities and equipment they currently or previously owned, including sites at which gas was manufactured or stored.

The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances for investigation and remediation costs (which include costs of demolition, removal, disposal, storage, replacement, containment and monitoring) and natural resource damages. Liability under these laws can be material and may be imposed for contamination from past acts, even though such past acts may have been lawful at the time they occurred. The sites at which the Utilities have been asserted to have liability under these laws, including their manufactured gas plant sites and any neighboring areas to which contamination may have migrated, are referred to herein as “Superfund Sites.”

For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of the undiscounted cost to investigate the sites and, for sites that have been investigated in whole or in part, the cost to remediate the sites, if remediation is necessary and if a reasonable estimate of such cost can be made. Remediation costs are estimated in light of the information available, applicable remediation standards and experience with similar sites.

The accrued liabilities and regulatory assets related to Superfund Sites at 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

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Other Material Contingencies

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Other Material Contingencies

Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately 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.

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Income Tax

6 Months Ended

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.

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Financial Information by Business Segment

6 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

Financial Information by Business Segment

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.

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Derivative Instruments and Hedging Activities

6 Months Ended

Jun. 30, 2017

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. 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.

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Fair Value Measurements

6 Months Ended

Jun. 30, 2017

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

The accounting rules for fair value measurements and disclosures define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.

The accounting rules for fair value measurements and disclosures established a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows:

• Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange.

• Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models.

• Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value.

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)
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 millionloss and $5 milliongain) 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 millionloss and $2 millionloss) 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 millionloss and $7 milliongain) 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 millionloss and $3 milliongain) on the consolidated income statement, respectively.

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Variable Interest Entities

6 Months Ended

Jun. 30, 2017

Equity Method Investments and Joint Ventures [Abstract]

Variable Interest Entities

Variable Interest Entities

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

CECONY has 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.

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New Financial Accounting Standards

6 Months Ended

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.

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Dispositions

6 Months Ended

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.

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New Financial Accounting Standards (Policies)

6 Months Ended

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.

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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.

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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

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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.

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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

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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

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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

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

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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

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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.

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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) 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.

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) 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.

Realized and Unrealized Gains or Losses on Commodity Derivatives

The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the three and 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).

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

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.

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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) 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.

Schedule of Commodity Derivatives

	Fair Value of Level 3 at June 30, 2017	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
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

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

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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

(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.

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General (Details)	6 Months Ended
	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

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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

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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

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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

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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

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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

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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

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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%

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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

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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%

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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

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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

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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

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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

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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

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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

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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

XML

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

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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

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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

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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

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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

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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

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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

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Income Tax (Details) - USD ($)	3 Months Ended		6 Months Ended
	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

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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

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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

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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

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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

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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

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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

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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

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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%

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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

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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

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Variable Interest Entities (Details) $ in Millions	6 Months Ended
	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%

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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