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 SEPTEMBER 30, 2016

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, or a smaller reporting company. See the definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

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

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 October 28, 2016, Con Edison had outstanding 304,727,523 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.
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.
CET Electric	Consolidated Edison Transmission, LLC
CET Gas	Con Edison Gas Pipeline and Storage, LLC
O&R	Orange and Rockland Utilities, Inc.
Pike	Pike County Light & Power Company
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
PAPUC	Pennsylvania Public Utility Commission
PJM	PJM Interconnection LLC
SEC	U.S. Securities and Exchange Commission
Accounting
ASU	Accounting Standards Update
GAAP	Generally Accepted Accounting Principles in the United States of America
OCI	Other Comprehensive Income
VIE	Variable interest entity

2

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
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
AFUDC	Allowance for funds used during construction
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
Third Quarter Form 10-Q	The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended September 30 of the current year
Form 10-K	The Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2015
LTIP	Long Term Incentive Plan
Moody’s	Moody’s Investors Service
REV	Reforming the Energy Vision
S&P	Standard & Poor’s Financial Services LLC
VaR	Value-at-Risk

3

TABLE OF CONTENTS

		PAGE
PART I—Financial Information
ITEM 1	Financial Statements (Unaudited)
	Con Edison
	Consolidated Income Statement	6
	Consolidated Statement of Comprehensive Income	7
	Consolidated Statement of Cash Flows	8
	Consolidated Balance Sheet	9
	Consolidated Statement of Equity	11
	CECONY
	Consolidated Income Statement	12
	Consolidated Statement of Comprehensive Income	13
	Consolidated Statement of Cash Flows	14
	Consolidated Balance Sheet	15
	Consolidated Statement of Shareholder’s Equity	17
	Notes to the Financial Statements (Unaudited)	18
ITEM 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	44
ITEM 3	Quantitative and Qualitative Disclosures About Market Risk	74
ITEM 4	Controls and Procedures	74
PART II—Other Information		75
ITEM 1	Legal Proceedings	75
ITEM 1A	Risk Factors	75
ITEM 6	Exhibits	75
	Signatures	76

4

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:

• 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;

• 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.

5

ConsolidatedEdison, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
	2016	2015	2016	2015
	(Millions of Dollars/ Except Share Data)
OPERATING REVENUES
Electric	$2,769	$2,762	$6,717	$6,937
Gas	235	237	1,246	1,293
Steam	63	58	406	529
Non-utility	350	386	999	1,088
TOTAL OPERATING REVENUES	3,417	3,443	9,368	9,847
OPERATING EXPENSES
Purchased power	798	860	2,047	2,404
Fuel	29	31	133	216
Gas purchased for resale	81	64	320	415
Other operations and maintenance	840	869	2,447	2,485
Depreciation and amortization	305	285	905	840
Taxes, other than income taxes	528	504	1,523	1,459
TOTAL OPERATING EXPENSES	2,581	2,613	7,375	7,819
Gain on sale of retail electric supply business	104	—	104	—
OPERATING INCOME	940	830	2,097	2,028
OTHER INCOME (DEDUCTIONS)
Investment and other income	51	12	70	31
Allowance for equity funds used during construction	3	1	7	3
Other deductions	(5)	(4)	(16)	(11)
TOTAL OTHER INCOME	49	9	61	23
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	989	839	2,158	2,051
INTEREST EXPENSE
Interest on long-term debt	174	157	504	469
Other interest	5	6	17	19
Allowance for borrowed funds used during construction	(1)	(1)	(4)	(2)
NET INTEREST EXPENSE	178	162	517	486
INCOME BEFORE INCOME TAX EXPENSE	811	677	1,641	1,565
INCOME TAX EXPENSE	314	249	602	548
NET INCOME	$497	$428	$1,039	$1,017
Net income per common share—basic	$1.63	$1.46	$3.47	$3.47
Net income per common share—diluted	$1.62	$1.45	$3.46	$3.46
DIVIDENDS DECLARED PER COMMON SHARE	$0.67	$0.65	$2.01	$1.95
AVERAGE NUMBER OF SHARES OUTSTANDING—BASIC (IN MILLIONS)	304.5	292.9	299.1	292.9
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS)	305.9	294.2	300.5	294.2

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

6

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
	2016	2015	2016	2015
	(Millions of Dollars)
NET INCOME	$497	$428	$1,039	$1,017
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	1	2	7
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	2	7
COMPREHENSIVE INCOME	$498	$429	$1,041	$1,024

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

7

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Nine Months Ended September 30,
	2016		2015
	(Millions of Dollars)
OPERATING ACTIVITIES
Net income	$1,039		$1,017
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	905		840
Deferred income taxes	524		466
Rate case amortization and accruals	(157)		(38)
Common equity component of allowance for funds used during construction	(7)		(3)
Net derivative (gains)/losses	(7)		(4)
Pre-tax gain on sale of retail electric supply business	(104)		—
Other non-cash items, net	99		73
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(138)		(82)
Materials and supplies, including fuel oil and gas in storage	15		32
Other receivables and other current assets	90		44
Income taxes receivable	100		194
Prepayments	(403)		(568)
Accounts payable	142		83
Pensions and retiree benefits obligations, net	464		566
Pensions and retiree benefits contributions	(510)		(753)
Accrued taxes	(21)		(19)
Accrued interest	66		48
Superfund and environmental remediation costs, net	68		23
Distributions from equity investments	45		29
Deferred charges, noncurrent assets and other regulatory assets	(104)		(17)
Deferred credits and other regulatory liabilities	116		220
Other current and noncurrent liabilities	114		48
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,336		2,199
INVESTING ACTIVITIES
Utility construction expenditures	(2,057)		(1,838)
Cost of removal less salvage	(149)		(156)
Non-utility construction expenditures	(436)		(366)
Investments in/acquisitions of renewable electric production and electric and gas transmission projects	(1,281)		(286)
Proceeds from sale of assets	250		—
Proceeds from the transfer of assets to NY Transco	122		—
Restricted cash	(21)		(23)
Other investing activities	(145)		(18)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,717)		(2,687)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(928)		360
Issuance of long-term debt	1,765		238
Retirement of long-term debt	(407)		(145)
Debt issuance costs	(16)		(2)
Common stock dividends	(570)		(560)
Issuance of common shares - public offering	702		—
Issuance of common shares for stock plans, net of repurchases	38		(9	)
Distribution to noncontrolling interest	(1)		—
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	583		(118)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(798)		(606)
BALANCE AT BEGINNING OF PERIOD	944		699
BALANCE AT END OF PERIOD	146		93
LESS: CHANGE IN CASH BALANCES HELD FOR SALE	(4	)	2
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	$150		$91
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$437		$411
Income taxes	$(144)		$(7)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$242		$204
Issuance of common shares for dividend reinvestment	$35		$11

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

8

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2016	December 31, 2015
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$150	$944
Special deposits	3	3
Accounts receivable – customers, less allowance for uncollectible accounts of $75 and $85 in 2016 and 2015, respectively	1,157	1,052
Other receivables, less allowance for uncollectible accounts of $13 and $11 in 2016 and 2015, respectively	165	304
Income taxes receivable	66	166
Accrued unbilled revenue	373	360
Fuel oil, gas in storage, materials and supplies, at average cost	335	350
Prepayments	580	177
Regulatory assets	119	132
Assets held for sale	—	157
Other current assets	206	191
TOTAL CURRENT ASSETS	3,154	3,836
INVESTMENTS	1,931	884
UTILITY PLANT, AT ORIGINAL COST
Electric	27,239	26,358
Gas	7,253	6,858
Steam	2,374	2,336
General	2,657	2,622
TOTAL	39,523	38,174
Less: Accumulated depreciation	8,451	8,044
Net	31,072	30,130
Construction work in progress	1,286	1,003
NET UTILITY PLANT	32,358	31,133
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $122 and $95 in 2016 and 2015, respectively	1,127	832
Construction work in progress	421	244
NET PLANT	33,906	32,209
OTHER NONCURRENT ASSETS
Goodwill	429	429
Intangible assets, less accumulated amortization of $5 and $4 in 2016 and 2015, respectively	—	2
Regulatory assets	7,544	8,096
Other deferred charges and noncurrent assets	352	186
TOTAL OTHER NONCURRENT ASSETS	8,325	8,713
TOTAL ASSETS	$47,316	$45,642

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

9

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2016	December 31, 2015
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$346	$739
Notes payable	601	1,529
Accounts payable	1,113	1,008
Customer deposits	356	354
Accrued taxes	41	62
Accrued interest	202	136
Accrued wages	101	97
Fair value of derivative liabilities	70	66
Regulatory liabilities	123	115
Liabilities held for sale	—	89
Other current liabilities	638	525
TOTAL CURRENT LIABILITIES	3,591	4,720
NONCURRENT LIABILITIES
Provision for injuries and damages	170	185
Pensions and retiree benefits	2,197	2,911
Superfund and other environmental costs	752	765
Asset retirement obligations	254	242
Fair value of derivative liabilities	52	39
Deferred income taxes and unamortized investment tax credits	10,155	9,537
Regulatory liabilities	1,920	1,977
Other deferred credits and noncurrent liabilities	203	199
TOTAL NONCURRENT LIABILITIES	15,703	15,855
LONG-TERM DEBT	13,747	12,006
EQUITY
Common shareholders’ equity	14,267	13,052
Noncontrolling interest	8	9
TOTAL EQUITY (See Statement of Equity)	14,275	13,061
TOTAL LIABILITIES AND EQUITY	$47,316	$45,642

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

10

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, 2014	293	$32	$4,991	$8,691	23	$(1,032)	$(61)	$(45)	$9	$12,585
Net income				370						370
Common stock dividends				(190)						(190)
Issuance of common shares for stock plans, net of repurchases	—		2		—	(2)				—
Other comprehensive income								5		5
BALANCE AS OF MARCH 31, 2015	293	$32	$4,993	$8,871	23	$(1,034)	$(61)	$(40)	$9	$12,770
Net income				219						219
Common stock dividends				(190)						(190)
Issuance of common shares for stock plans, net of repurchases	—		—		—	(3)				(3)
Other comprehensive income								1		1
BALANCE AS OF JUNE 30, 2015	293	$32	$4,993	$8,900	23	$(1,037)	$(61)	$(39)	$9	$12,797
Net income				428						428
Common stock dividends				(191)						(191)
Issuance of common shares for stock plans, net of repurchases	—		15		—	(1)				14
Other comprehensive income								1		1
BALANCE AS OF SEPTEMBER 30, 2015	293	$32	$5,008	$9,137	23	$(1,038)	$(61)	$(38)	$9	$13,049
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
BALANCE AS OF JUNE 30, 2016	304	$33	$5,807	$9,264	23	$(1,038)	$(83)	$(33)	$8	$13,958
Net income				497						497
Common stock dividends				(204)						(204)
Issuance of common shares for stock plans	1		23							23
Other comprehensive income								1		1
BALANCE AS OF SEPTEMBER 30, 2016	305	$33	$5,830	$9,557	23	$(1,038)	$(83)	$(32)	$8	$14,275

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

11

Consolidated Edison Company of New York, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
	2016	2015	2016	2015
	(Millions of Dollars)
OPERATING REVENUES
Electric	$2,557	$2,558	$6,222	$6,416
Gas	208	213	1,113	1,177
Steam	63	58	406	529
TOTAL OPERATING REVENUES	2,828	2,829	7,741	8,122
OPERATING EXPENSES
Purchased power	495	526	1,216	1,423
Fuel	29	31	133	216
Gas purchased for resale	34	30	217	282
Other operations and maintenance	724	750	2,105	2,140
Depreciation and amortization	278	262	825	773
Taxes, other than income taxes	502	485	1,446	1,399
TOTAL OPERATING EXPENSES	2,062	2,084	5,942	6,233
OPERATING INCOME	766	745	1,799	1,889
OTHER INCOME (DEDUCTIONS)
Investment and other income	4	(1)	6	3
Allowance for equity funds used during construction	2	1	6	3
Other deductions	(4)	(3)	(10)	(10)
TOTAL OTHER INCOME (DEDUCTIONS)	2	(3)	2	(4)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	768	742	1,801	1,885
INTEREST EXPENSE
Interest on long-term debt	150	141	440	423
Other interest	5	5	14	14
Allowance for borrowed funds used during construction	(1)	(1)	(3)	(2)
NET INTEREST EXPENSE	154	145	451	435
INCOME BEFORE INCOME TAX EXPENSE	614	597	1,350	1,450
INCOME TAX EXPENSE	226	222	491	515
NET INCOME	$388	$375	$859	$935

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

12

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
	2016	2015	2016	2015
	(Millions of Dollars)
NET INCOME	$388	$375	$859	$935
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	—	1	1	2
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	—	1	1	2
COMPREHENSIVE INCOME	$388	$376	$860	$937

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

13

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Nine Months Ended September 30,
	2016	2015
	(Millions of Dollars)
OPERATING ACTIVITIES
Net income	$859	$935
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	825	773
Deferred income taxes	569	391
Rate case amortization and accruals	(170)	(57)
Common equity component of allowance for funds used during construction	(6)	(3)
Other non-cash items, net	7	13
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(79)	(51)
Materials and supplies, including fuel oil and gas in storage	15	34
Other receivables and other current assets	18	60
Accounts receivable from affiliated companies	38	(32)
Prepayments	(351)	(336)
Accounts payable	82	18
Accounts payable to affiliated companies	8	5
Pensions and retiree benefits obligations, net	439	530
Pensions and retiree benefits contributions	(472)	(700)
Superfund and environmental remediation costs, net	76	21
Accrued taxes	(17)	(1)
Accrued taxes to affiliated companies	(2)	(8)
Accrued interest	43	37
Deferred charges, noncurrent assets and other regulatory assets	(153)	(49)
Deferred credits and other regulatory liabilities	165	222
Other current and noncurrent liabilities	123	—
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,017	1,802
INVESTING ACTIVITIES
Utility construction expenditures	(1,932)	(1,732)
Cost of removal less salvage	(146)	(149)
Proceeds from the transfer of assets to NY Transco	122	—
Restricted cash	13	(19)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,943)	(1,900)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(553)	199
Issuance of long-term debt	550	—
Retirement of long-term debt	(400)	—
Debt issuance costs	(6)	(1)
Capital contribution by parent	76	—
Dividend to parent	(558)	(694)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(891)	(496)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(817)	(594)
BALANCE AT BEGINNING OF PERIOD	843	645
BALANCE AT END OF PERIOD	$26	$51
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$386	$376
Income taxes	$(130)	$143
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$195	$152

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

14

Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2016	December 31, 2015
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$26	$843
Special deposits	2	2
Accounts receivable – customers, less allowance for uncollectible accounts of $70 and $80 in 2016 and 2015, respectively	1,076	987
Other receivables, less allowance for uncollectible accounts of $12 and $11 in 2016 and 2015, respectively	55	70
Accrued unbilled revenue	330	327
Accounts receivable from affiliated companies	152	190
Fuel oil, gas in storage, materials and supplies, at average cost	273	288
Prepayments	464	113
Regulatory assets	111	121
Other current assets	98	131
TOTAL CURRENT ASSETS	2,587	3,072
INVESTMENTS	318	286
UTILITY PLANT, AT ORIGINAL COST
Electric	25,648	24,828
Gas	6,564	6,191
Steam	2,374	2,336
General	2,437	2,411
TOTAL	37,023	35,766
Less: Accumulated depreciation	7,750	7,378
Net	29,273	28,388
Construction work in progress	1,200	922
NET UTILITY PLANT	30,473	29,310
NON-UTILITY PROPERTY
Non-utility property, less accumulated depreciation of $25 in 2016 and 2015	4	5
NET PLANT	30,477	29,315
OTHER NONCURRENT ASSETS
Regulatory assets	6,986	7,482
Other deferred charges and noncurrent assets	68	75
TOTAL OTHER NONCURRENT ASSETS	7,054	7,557
TOTAL ASSETS	$40,436	$40,230

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

15

Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2016	December 31, 2015
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$250	$650
Notes payable	480	1,033
Accounts payable	838	771
Accounts payable to affiliated companies	20	12
Customer deposits	341	339
Accrued taxes	32	49
Accrued taxes to affiliated companies	—	2
Accrued interest	161	118
Accrued wages	92	88
Fair value of derivative liabilities	61	50
Regulatory liabilities	96	84
Other current liabilities	558	443
TOTAL CURRENT LIABILITIES	2,929	3,639
NONCURRENT LIABILITIES
Provision for injuries and damages	164	178
Pensions and retiree benefits	1,895	2,565
Superfund and other environmental costs	661	665
Asset retirement obligations	241	234
Fair value of derivative liabilities	45	36
Deferred income taxes and unamortized investment tax credits	9,472	8,755
Regulatory liabilities	1,725	1,789
Other deferred credits and noncurrent liabilities	177	167
TOTAL NONCURRENT LIABILITIES	14,380	14,389
LONG-TERM DEBT	11,334	10,787
SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	11,793	11,415
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$40,436	$40,230

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

16

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, 2014	235	$589	$4,234	$7,399	$(962)	$(61)	$(11)	$11,188
Net income				348				348
Common stock dividend to parent				(338)				(338)
Other comprehensive income							—	—
BALANCE AS OF MARCH 31, 2015	235	$589	$4,234	$7,409	$(962)	$(61)	$(11)	$11,198
Net income				211				211
Common stock dividend to parent				(178)				(178)
Other comprehensive income							1	1
BALANCE AS OF JUNE 30, 2015	235	$589	$4,234	$7,442	$(962)	$(61)	$(10)	$11,232
Net income				375				375
Common stock dividend to parent				(178)				(178)
Other comprehensive income							1	1
BALANCE AS OF SEPTEMBER 30, 2015	235	$589	$4,234	$7,639	$(962)	$(61)	$(9)	$11,430
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
Net income				388				388
Common stock dividend to parent				(186)				(186)
Capital contribution by parent			25					25
Other comprehensive income							—	—
BALANCE AS OF SEPTEMBER 30, 2016	235	$589	$4,323	$7,912	$(962)	$(61)	$(8)	$11,793

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

17

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 Con Edison’s other utility subsidiary, Orange and Rockland Utilities, Inc. (O&R), Con Edison Transmission, Inc. (Con Edison Transmission) and Con Edison’s competitive energy businesses in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R.

As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself.

The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies’ separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2015 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Report on Form 10-Q for the quarterly periods ended March 31, 2016 and June 30, 2016. Certain prior period amounts have been reclassified to conform to the current period presentation.

Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiary, provides electric service in southeastern New York and northern New Jersey and gas service in southeastern New York. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company which provides energy-related products and services to retail customers; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects. In addition, Con Edison has a subsidiary, Con Edison Transmission, that invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See Note P.

Note A – Summary of Significant Accounting Policies

Earnings Per Common Share

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

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2016	2015
Net income	$497	$428	$1,039	$1,017
Weighted average common shares outstanding – basic	304.5	292.9	299.1	292.9
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	305.9	294.2	300.5	294.2
Net income per common share – basic	$1.63	$1.46	$3.47	$3.47
Net income per common share – diluted	$1.62	$1.45	$3.46	$3.46

18

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

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(33)	$(39)	$(8)	$(10)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015 (a)(b)	1	1	—	1
Current period OCI, net of taxes	1	1	—	1
Ending balance, accumulated OCI, net of taxes	$(32)	$(38)	$(8)	$(9)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(45)	$(9)	$(11)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively	(1)	3	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) and $(3) for Con Edison in 2016 and 2015 (a)(b)	3	4	1	2
Current period OCI, net of taxes	2	7	1	2
Ending balance, accumulated OCI, net of taxes	$(32)	$(38)	$(8)	$(9)

(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.

Note B — Regulatory Matters

Rate Plans

CECONY - Electric

In September 2016, CECONY, the staff of the New York State Public Service Commission (NYSPSC) and other parties entered into a Joint Proposal for a CECONY electric rate plan for the three-year period January 2017 through December 2019. The Joint Proposal is subject to NYSPSC approval. The following table contains a summary of the electric rate plan.

19

Effective period	January 2017 - December 2019
Base rate changes (a)	Yr. 1 - $195 million Yr. 2 - $155 million Yr. 3 - $155 million
Amortizations to income of net regulatory (assets) liabilities	Yr. 1 - $84 million Yr. 2 - $83 million Yr. 3 - $69 million
Other revenue sources	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $28 million; Yr. 2 - $47 million; and Yr. 3 - $64 million.
Revenue decoupling mechanism	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $376 million; Yr. 2 - $383 million; and Yr. 3 - $395 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes(b), municipal infrastructure support costs(c), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(d)
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $21,689 million; Yr. 2 - $22,338 million; Yr. 3 - $23,002 million AMI: Yr. 1 - $126 million; Yr. 2 - $257 million; Yr. 3 - $415 million
Average rate base	Yr. 1 - $18,902 million Yr. 2 - $19,530 million Yr. 3 - $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.00 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent

(a) The electric base rate increases shown above are in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the current rate plan. At the NYSPSC’s option, these increases may be implemented with increases of $199 million in each rate year.

(b) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(c) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral of 30 percent of the amount reflected in rates.

(d) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers.

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

CECONY - Gas

In September 2016, CECONY, the staff of the NYSPSC and other parties entered into a Joint Proposal for a CECONY gas rate plan for the three-year period January 2017 through December 2019. The Joint Proposal is subject to NYSPSC approval. The following table contains a summary of the gas rate plan.

20

Effective period	January 2017 - December 2019
Base rate changes	Yr. 1 - $(5) million(a) Yr. 2 - $92 million Yr. 3 - $90 million
Amortizations to income of net regulatory (assets) liabilities	Yr. 1 - $39 million Yr. 2 - $37 million Yr. 3 - $36 million
Other revenue sources	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 - $7 million; Yr. 2 - $8 million; and Yr. 3 - $8 million.
Revenue decoupling mechanism	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 - $68 million; Yr. 2 - $75 million; and Yr. 3 - $83 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(b)
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $5,844 million; Yr. 2 - $6,512 million; Yr. 3 - $7,177 million AMI: Yr. 1 - $27 million; Yr. 2 - $57 million; Yr. 3 - $100 million
Average rate base	Yr. 1 - $4,841 million Yr. 2 - $5,395 million Yr. 3 - $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.00 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent

(a) The base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the current rate plan.

(b) See footnotes (b), (c) and (d) to the table under “CECONY-Electric,” above.

Rockland Electric Company (RECO)

In April 2016, RECO filed a request with the New Jersey Board of Public Utilities for an electric rate increase of $10 million, effective March 2017. The filing reflected a return on common equity of 10.20 percent and a common equity ratio of 49.81 percent. In October 2016, RECO filed an update to its April 2016 request. The company decreased its requested March 2017 rate increase by $4 million to $6 million. The updated filing reflects a return on common equity of 10.20 percent and a common equity ratio of 50.15 percent. The filing reflects continuation of provisions pursuant to which the company recovers its purchased power and fuel costs from customers. 

21

Other Regulatory Matters

In April 2016, the NYSPSC approved the September 2015 Joint Proposal among CECONY, the NYSPSC staff and others with respect to the prudence proceeding the NYSPSC commenced in February 2009 and related matters. Pursuant to the Joint Proposal, the company is required to credit $116 million to customers and, for the period 2017 through 2044, to not seek to recover from customers an aggregate $55 million relating to return on its capital expenditures. In addition, the company’s revenues that were made subject to potential refund in this proceeding are no longer subject to refund. At September 30, 2016, the company had a $96 million regulatory liability for the remaining amount to be credited to customers related to this matter.

In June 2014, the NYSPSC initiated a proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. New York State regulations require gas utilities to qualify and, except in certain circumstances, annually requalify workers that perform fusion to join plastic pipe. The NYSPSC directed the New York gas utilities to provide information in this proceeding about their compliance with the qualification and requalification requirements and related matters; their procedures for compliance with all gas safety regulations; and their annual chief executive officer certifications regarding these and other procedures. CECONY’s qualification and requalification procedures had not included certain required testing to evaluate specimen fuses. In addition, CECONY and O&R had not timely requalified certain workers that had been qualified under their respective procedures to perform fusion to join plastic pipe. CECONY and O&R have requalified their workers who perform plastic pipe fusions. In May 2015, the NYSPSC, which indicated that it would address enforcement at a later date, ordered CECONY, O&R and other gas utilities to perform risk assessment and remediation plans, additional leakage surveying and reporting; CECONY to hire an independent statistician to develop a risk assessment and remediation plan; and the gas utilities to implement certain new plastic fusion requirements. In December 2015, the NYSPSC staff informed O&R that the company had satisfactorily completed its risk assessment and remediation plan. CECONY submitted its risk assessment and remediation plan to the NYSPSC staff in October 2016.

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

At September 30, 2016, CECONY had a $28 million regulatory liability related to the June 2014 plastic fusion proceeding and the November 2015 order to show cause. The company is unable to estimate the amount or range of its possible loss related to these matters in excess of this regulatory liability.

CECONY has incurred costs for gas emergency response activities in 2014, 2015 and 2016 in excess of amounts reflected in the company’s gas rate plan. The company has requested NYSPSC authorization to defer as a regulatory asset $29 million and $35 million of such incremental costs incurred in 2014 and 2015, respectively. The company estimates that it will incur $37 million of such incremental costs in 2016. At September 30, 2016, the company had not deferred any such incremental costs.

22

Regulatory Assets and Liabilities

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$3,369	$3,876	$3,220	$3,697
Future income tax	2,429	2,350	2,312	2,232
Environmental remediation costs	823	904	720	800
Revenue taxes	298	253	283	240
Deferred storm costs	89	185	30	110
Deferred derivative losses	55	50	49	46
Unamortized loss on reacquired debt	45	50	43	48
Surcharge for New York State assessment	43	44	40	40
O&R property tax reconciliation	39	46	—	—
Pension and other postretirement benefits deferrals	34	45	3	16
Net electric deferrals	29	44	29	44
Preferred stock redemption	25	26	25	26
O&R transition bond charges	16	21	—	—
Workers’ compensation	15	11	15	11
Recoverable energy costs	7	16	5	15
Other	228	175	212	157
Regulatory assets – noncurrent	7,544	8,096	6,986	7,482
Deferred derivative losses	94	113	87	103
Recoverable energy costs	25	19	24	18
Regulatory assets – current	119	132	111	121
Total Regulatory Assets	$7,663	$8,228	$7,097	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$713	$676	$602	$570
Property tax reconciliation	205	303	205	303
Pension and other postretirement benefit deferrals	163	76	130	46
Net unbilled revenue deferrals	121	109	121	109
Prudence proceeding	96	99	96	99
Unrecognized other postretirement costs	91	28	91	28
New York State income tax rate change	66	75	64	72
Base rate change deferrals	62	128	62	128
Variable-rate tax-exempt debt – cost rate reconciliation	60	70	52	60
Carrying charges on repair allowance and bonus depreciation	57	49	56	48
Earnings sharing - electric, gas and steam	34	80	26	80
Net utility plant reconciliations	27	32	27	31
Property tax refunds	12	44	12	44
World Trade Center settlement proceeds	5	21	5	21
Other	208	187	176	150
Regulatory liabilities – noncurrent	1,920	1,977	1,725	1,789
Revenue decoupling mechanism	74	45	70	45
Refundable energy costs	37	64	18	33
Deferred derivative gains	12	6	8	6
Regulatory liabilities – current	123	115	96	84
Total Regulatory Liabilities	$2,043	$2,092	$1,821	$1,873

23

Note C — Capitalization

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

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

In September 2016, CECONY redeemed at maturity $400 million aggregate principal amount of 5.50 percent debentures. In September 2016, O&R agreed to issue and sell for delivery in December 2016 $75 million aggregate principal amount of 3.88 percent debentures, due 2046. In October 2016, O&R redeemed at maturity $75 million aggregate principal amount of 5.45 percent debentures.

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

(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,093	$16,325	$12,745	$13,856
CECONY	$11,584	$13,564	$11,437	$12,427

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $15,689 million and $636 million of the fair value of long-term debt at September 30, 2016 are classified as Level 2 and Level 3, respectively. For CECONY, $12,928 million and $636 million of the fair value of long-term debt at September 30, 2016 are classified as Level 2 and Level 3, respectively (see Note L). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

Note D — Short-Term Borrowing

At September 30, 2016, Con Edison had $601 million of commercial paper outstanding of which $480 million was outstanding under CECONY’s program. The weighted average interest rate at September 30, 2016 was 0.7 percent for both Con Edison and CECONY. At December 31, 2015, Con Edison had $1,529 million of commercial paper outstanding of which $1,033 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2015 was 0.7 percent for both Con Edison and CECONY.

At September 30, 2016 and December 31, 2015, no loans were outstanding under the credit agreement (Credit Agreement) and $2 million (including $2 million for CECONY) and $15 million of letters of credit were outstanding under the Credit Agreement, respectively.

Note E — Pension Benefits

Total Periodic Benefit Cost

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

24

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$69	$74	$65	$70
Interest cost on projected benefit obligation	149	144	140	135
Expected return on plan assets	(237)	(222)	(225)	(210)
Recognition of net actuarial loss	149	194	141	183
Recognition of prior service costs	1	1	—	—
NET PERIODIC BENEFIT COST	$131	$191	$121	$178
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$131	$192	$121	$179
Cost capitalized	(51)	(80)	(49)	(76)
Reconciliation to rate level	10	(14)	13	(14)
Cost charged to operating expenses	$90	$98	$85	$89

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$207	$223	$194	$209
Interest cost on projected benefit obligation	447	431	419	404
Expected return on plan assets	(711)	(664)	(674)	(630)
Recognition of net actuarial loss	447	581	424	550
Recognition of prior service costs	3	3	1	1
NET PERIODIC BENEFIT COST	$393	$574	$364	$534
Amortization of regulatory asset	—	2	—	2
TOTAL PERIODIC BENEFIT COST	$393	$576	$364	$536
Cost capitalized	(157)	(224)	(148)	(214)
Reconciliation to rate level	35	(56)	39	(56)
Cost charged to operating expenses	$271	$296	$255	$266

Expected Contributions

Based on estimates as of September 30, 2016, the Companies expect to make contributions to the pension plans during 2016 of $508 million (of which $469 million is to be contributed by CECONY). The Companies’ policy is to fund the total periodic benefit cost of the qualified plan to the extent tax deductible and to also contribute to the non-qualified supplemental plans. During the first nine months of 2016, the Companies contributed $504 million (of which $466 million was contributed by CECONY) to the pension plans. CECONY also contributed $17 million to its external trust for 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 nine months ended September 30, 2016 and 2015 were as follows:

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

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	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost	$13	$15	$10	$11
Interest cost on accumulated other postretirement benefit obligation	36	38	30	32
Expected return on plan assets	(58)	(59)	(50)	(51)
Recognition of net actuarial loss	4	24	2	21
Recognition of prior service cost	(15)	(15)	(11)	(10)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(20)	$3	$(19)	$3
Cost capitalized	5	(2)	5	(2)
Reconciliation to rate level	20	12	19	5
Cost charged to operating expenses	$5	$13	$5	$6

Contributions

During the first nine months of 2016, the Companies contributed $6 million, nearly all of which was contributed by CECONY, to the other postretirement benefit plans. 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 September 30, 2016 and December 31, 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$664	$679	$574	$579
Other Superfund Sites	88	86	87	86
Total	$752	$765	$661	$665
Regulatory assets	$823	$904	$720	$800

Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available,

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the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The Companies are unable to estimate the time period over which the remaining accrued liability will be incurred because, among other things, the required remediation has not been determined for some of the sites. Under their current rate plans, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs.

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$8	$6	$5	$6

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$20	$21	$10	$18

Con Edison and CECONY received $1 million in insurance recoveries for the three and nine months ended September 30, 2016. No insurance recoveries were received by Con Edison or CECONY for the three and nine months ended September 30, 2015.

In 2015, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $2.8 billion and $2.7 billion, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different.

Asbestos Proceedings

Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, which are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At September 30, 2016, Con Edison and CECONY had accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. The estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Trial courts have begun, and unless otherwise determined by an appellate court may continue, to apply a different standard for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. Under its current rate plans, CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims.

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at September 30, 2016 and December 31, 2015 were as follows:

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	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$90	$86	$85	$81
Regulatory assets – workers’ compensation	$15	$11	$15	$11

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 sixty suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs to satisfy its liability to others in connection with the suits. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At September 30, 2016, the company has accrued its estimated liability for the suits of $30 million and an insurance receivable of $39 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 Street in Manhattan were destroyed by an explosion and fire. CECONY had delivered gas to the buildings through service lines from a distribution main located below ground on Park Avenue. Eight people died and more than 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC (which also conducted an investigation). In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. Approximately seventy 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 September 30, 2016, the company had not accrued a liability for damages related to the incident.

Other Contingencies

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

Guarantees

Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled $2,422 million and $2,856 million at September 30, 2016 and December 31, 2015, respectively.

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

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$618	$430		$—	$1,048
Energy transactions	635	57	91		783
Renewable electric production projects	445	—	18		463
Other	128	—	—		128
Total	$1,826	$487	$109		$2,422

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

Energy Transactions — Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Guarantee amounts shown above include $123 million of guarantees or other credit support 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. See Note P. As part of the sale agreement, the purchaser has agreed to pay Con Edison Solutions for draws on such guarantees or other credit support.

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

Other — Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects and operation of solar energy facilities of Con Edison Solutions and Con Edison Development, respectively. Other guarantees also includes Con Edison's guarantee (subject to a $53 million maximum amount) of certain obligations of Con Edison Solutions under its agreement to sell its retail electric supply business. See Note P. 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 increased to $314 million for the three months ended September 30, 2016 from $249 million for the three months ended September 30, 2015. Con Edison's effective tax rate for the three months ended September 30, 2016 and 2015 was 39 percent and 37 percent, respectively. The increase in Con Edison's effective tax rate is primarily due to higher state income taxes and a decrease in tax benefits for plant-related flow through items, offset in part by higher tax benefits for injuries and damages payments, research and development tax credits and renewable energy tax credits.

CECONY’s income tax expense increased to $226 million for the three months ended September 30, 2016 from $222 million for the three months ended September 30, 2015. CECONY's effective tax rate for the three months ended September 30, 2016 and 2015 was 37 percent. The decrease in tax benefits for plant-related flow through items, were more than offset by lower state income taxes and increased tax benefits as a result of higher injuries and damages payments and research and development tax credits.

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Con Edison’s income tax expense increased to $602 million for the nine months ended September 30, 2016 from $548 million for the nine months ended September 30, 2015. Con Edison's effective tax rate for the nine months ended September 30, 2016 and 2015 was 37 percent and 35 percent, respectively. The increase in Con Edison's effective tax rate is primarily due to higher state income taxes and a decrease in tax benefits for plant-related flow through items, offset in part by higher tax benefits for injuries and damages payments, research and development tax credits and renewable energy tax credits.

CECONY’s income tax expense decreased to $491 million for the nine months ended September 30, 2016 from $515 million for the nine months ended September 30, 2015. CECONY's effective tax rate for the nine months ended September 30, 2016 and 2015 was 36 percent and 35 percent, respectively. The increase in CECONY's effective tax rate is primarily related to a decrease in tax benefits for plant-related flow through items, offset in part by lower state income taxes and increased research and development tax credits.

In September 2016, Con Edison filed its 2015 federal income tax return, requesting a refund of $19 million of estimated tax payments and, in October 2016, the company received the refund. The company carried back a 2015 net operating loss to 2007, requesting a refund of $16 million of federal income tax and, in October 2016, the company received the refund. Con Edison anticipates a federal net operating loss for 2016, primarily due to bonus depreciation. Con Edison expects to carryback a portion of its 2016 net operating loss and recover $32 million of income tax. General business tax credits that became available as a result of the net operating loss carryback, as well as the remaining 2016 net operating loss will be carried forward to future tax years. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized.

Uncertain Tax Positions

At September 30, 2016, the estimated liability for uncertain tax positions for Con Edison was $37 million ($5 million for CECONY). Con Edison reasonably expects to resolve approximately $29 million ($20 million, net of federal taxes) of its uncertain tax positions within the next twelve months, of which the entire amount, if recognized, would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $5 million ($4 million, net of federal taxes), of which the entire amount, if recognized, would reduce CECONY’s effective tax rate. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $37 million ($25 million, net of federal taxes).

The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In the three and nine months ended September 30, 2016, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At September 30, 2016 and December 31, 2015, 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 prior to June 2016 were CECONY’s regulated utility activities, O&R’s regulated utility activities and Con Edison’s competitive energy businesses. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. In 2016, Con Edison Transmission began investing, through CET Electric and CET Gas, in electric transmission and gas pipeline and storage assets (see Note P). As a result of these investments, in June 2016 Con Edison changed its business segments to add Con Edison Transmission as a separate reportable segment based on management’s reporting and decision-making, including performance evaluation and resource allocation. For comparison purposes, the previously reported financial information by business segments was reclassified to reflect the current business segment presentation.

The financial data for the business segments are as follows:

	As of and for the Three Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)		Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$2,557	$2,558	$5		$4		$217	$207	$841	$811	$2	$(2)	$117	$111	$275	$260	$30,580	$30,369	$411	$419
Gas	208	213	1		1		41	35	(28)	(17)	—	(1)	27	24	(24)	(17)	7,300	6,687	224	178
Steam	63	58	22		22		20	20	(47)	(49)	—	—	10	10	(17)	(18)	2,556	2,614	24	27
Consolidation adjustments	—	—	(28)		(27)		—	—	—	—	—	—	—	—	—	—	—	—	—	—
Total CECONY	$2,828	$2,829		$—		$—	$278	$262	$766	$745	$2	$(3)	$154	$145	$234	$225	$40,436	$39,670	$659	$624
O&R
Electric	$213	$205		$—		$—	$12	$13	$55	$51	$1	$(4)	$6	$6	$20	$17	$1,985	$1,959	$24	$26
Gas	27	24	—		—		5	4	(7)	(9)	—	(1)	3	3	(4)	(5)	799	754	14	12
Total O&R	$240	$229		$—		$—	$17	$17	$48	$42	$1	$(5)	$9	$9	$16	$12	$2,784	$2,713	$38	$38
Competitive energy businesses	$350	$386	$(2)		$(2)		$11	$6	$125	$43	$27	$17	$7	$2	$67	$21	$2,394	$1,547	$121	$212
Con Edison Transmission	—	—	—		—		—	—	(1)	—	20	—	3	—	—	—	1,072	2	—	—
Other (a)	(1)	(1)	2		2		(1)	—	2	—	(1)	—	5	6	4	2	630	1,039	—	—
Total Con Edison	$3,417	$3,443		$—		$—	$305	$285	$940	$830	$49	$9	$178	$162	$321	$260	$47,316	$44,971	$818	$874

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

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	As of and for the Nine Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)		Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$6,222	$6,416	$13		$13		$645	$610	$1,487	$1,511	$3	$(3)	$342	$333	$412	$401	$30,580	$30,369	$1,133	$1,165
Gas	1,113	1,177	4		4		118	105	273	278	(1)	(1)	79	71	73	82	7,300	6,687	589	466
Steam	406	529	65		65		62	58	39	100	—	—	30	31	18	42	2,556	2,614	74	65
Consolidation adjustments	—	—	(82)		(82)		—	—	—	—	—	—	—	—	—	—	—	—	—	—
Total CECONY	$7,741	$8,122		$—		$—	$825	$773	$1,799	$1,889	$2	$(4)	$451	$435	$503	$525	$40,436	$39,670	$1,796	$1,696
O&R
Electric	$497	$523		$—		$—	$37	$38	$86	$85	$1	$(2)	$19	$18	$27	$26	$1,985	$1,959	$70	$72
Gas	133	117	—		—		13	13	28	—	—	(2)	9	9	8	(4)	799	754	36	29
Total O&R	$630	$640		$—		$—	$50	$51	$114	$85	$1	$(4)	$28	$27	$35	$22	$2,784	$2,713	$106	$101
Competitive energy businesses	$998	$1,087	$7		$(5)		$30	$16	$184	$53	$36	$33	$23	$5	$76	$24	$2,394	$1,547	$677	$676
Con Edison Transmission	—	—	—		—		—	—	(1)	—	23	—	4	—	—	—	1,072	2	—	—
Other (a)	(1)	(2)	(7)		5		—	—	1	1	(1)	(2)	11	19	6	3	630	1,039	—	—
Total Con Edison	$9,368	$9,847		$—		$—	$905	$840	$2,097	$2,028	$61	$23	$517	$486	$620	$574	$47,316	$44,971	$2,579	$2,473

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

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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.

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

(Millions of Dollars)	2016				2015
Balance Sheet Location	Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)		Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)
Con Edison
Fair value of derivative assets
Current	$75	$(60)	$15	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	58	(57)	1		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$133	$(117)	$16		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(143)	$73	$(70)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(111)	59	(52)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(254)	$132	$(122)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(121)	$15	$(106)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(46)	$6	(b)	$40	$(32)	$8	(b)
Noncurrent	45	(45)	—		48	(47)	1
Total fair value of derivative assets	$97	$(91)	$6		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(122)	$61	$(61)		$(121)	$71	$(50)
Noncurrent	(92)	47	(45)		(92)	56	(36)
Total fair value of derivative liabilities	$(214)	$108	$(106)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(117)	$17	$(100)	(b)	$(125)	$48	$(77)	(b)

(a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount.

(b) At September 30, 2016 and December 31, 2015, margin deposits for Con Edison ($12 million and $26 million, respectively) and CECONY ($12 million and $26 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

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

The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements. Con Edison’s competitive energy businesses record realized and unrealized gains and losses on their derivative contracts in purchased power, gas purchased for resale and non-utility revenue in the

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reporting period in which they occur. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2016 and 2015:

		For the Three Months Ended September 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(1)		$(1)		$(3)		$(1)
Noncurrent	Deferred derivative gains	(2)		—		—		—
Total deferred gains/(losses)		$(3)		$(1)		$(3)		$(1)
Current	Deferred derivative losses	$(19)		$8		$(18)		$8
Current	Recoverable energy costs	(39)		(53)		(35)		(49)
Noncurrent	Deferred derivative losses	(17)		14		(14)		13
Total deferred gains/(losses)		$(75)		$(31)		$(67)		$(28)
Net deferred gains/(losses)		$(78)		$(32)		$(70)		$(29)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(37)	(a)	$(31)	(b)		$—		$—
	Gas purchased for resale	(38)		(26)		—		—
	Non-utility revenue	(2)	(a)	5	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(77)		$(52)			$—		$—

(a) For the three months ended September 30, 2016, Con Edison recorded unrealized losses in non-utility operating revenue ($2 million) and purchase power expense ($23 million).

(b) For the three months ended September 30, 2015, Con Edison recorded in purchased power expense an unrealized pre-tax gain of $12 million.

		For the Nine Months Ended September 30,
		Con Edison					CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015			2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$6			$—		$2		$1
Noncurrent	Deferred derivative gains	(1)		—			(1)		—
Total deferred gains/(losses)		$5			$—		$1		$1
Current	Deferred derivative losses	$19		$40			$16		$40
Current	Recoverable energy costs	(163)		(92)			(148)		(87)
Noncurrent	Deferred derivative losses	(5)		(7)			(3)		(5)
Total deferred gains/(losses)		$(149)		$(59)			$(135)		$(52)
Net deferred gains/(losses)		$(144)		$(59)			$(134)		$(51)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(106)	(a)	$(60)		(b)		$—		$—
	Gas purchased for resale	(72)		(94)			—		—
	Non-utility revenue	15	(a)	20		(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(163)		$(134)				$—		$—

(a) For the nine months ended September 30, 2016, Con Edison recorded unrealized gains and losses in non-utility operating revenue ($3 million loss) and purchase power expense ($11 million gain).

(b) For the nine months ended September 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($3 million loss) and purchased power expense ($6 million gain).

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

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	22,797,395	15,472	69,954,738	1,344,000
CECONY	20,724,225	9,000	70,100,000	1,344,000

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

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

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

At September 30, 2016, Con Edison and CECONY had $141 million and $13 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $77 million with independent system operators, $34 million with investment-grade counterparties, $20 million with commodity exchange brokers, and $10 million with non-investment grade/non-rated counterparties. CECONY’s net credit exposure consisted of $12 million with commodity exchange brokers and $1 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 September 30, 2016:

(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$111		$97
Collateral posted	24		23
Additional collateral (b) (downgrade one level from current ratings)	18		15
Additional collateral (b) (downgrade to below investment grade from current ratings)	106	(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 competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $10 million at September 30, 2016. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) Derivative instruments that are net assets have been excluded from the table. At September 30, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $9 million.

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

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liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.

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

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

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

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

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

	2016					2015
(Millions of Dollars)	Level 1	Level 2	Level 3	Netting Adjustment (e)	Total	Level 1	Level 2	Level 3		Netting Adjustment (e)	Total
Con Edison
Derivative assets:
Commodity (a)(b)(c)	$6	$21	$6	$(5)	$28	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	—	—	—	—	—	63	1		(63)	1
Other (a)(b)(d)	224	113	—	—	337	185	112	—		—	297
Total assets	$230	$134	$6	$(5)	$365	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$3	$146	$5	$(32)	$122	$16	$153	$1		$(65)	$105
Commodity held for sale (f)	—	—	—	—	—	1	133	7		(63)	78
Total liabilities	$3	$146	$5	$(32)	$122	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$4	$7	$1	$6	$18	$1	$9	$8		$17	$35
Other (a)(b)(d)	200	108	—	—	308	171	105	—		—	276
Total assets	$204	$115	$1	$6	$326	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$2	$126	$1	$(23)	$106	$14	$129		$—	$(57)	$86

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(a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. There were no transfers between levels 1, 2 and 3 for the nine months ended September 30, 2016 and for the year ended December 31, 2015.

(b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.

(c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2016 and December 31, 2015, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.

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

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

(f) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet.

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

	Fair Value of Level 3 at September 30, 2016		Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
Con Edison – Commodity
Electricity	$(1)		Discounted Cash Flow	Forward energy prices (a)	$19.75-$80.00 per MWh
	1		Discounted Cash Flow	Forward capacity prices (a)	$2.68-$9.45 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)	52.8%-59.4%
				Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(44.9)%-58.9%
				Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(0.14)-$2.82 per MWh
Total Con Edison—Commodity	$1
CECONY—Commodity
Electricity	$(1)		Discounted Cash Flow	Forward energy prices (a)	$21.10-$80.00 per MWh
Transmission Congestion Contracts	$1		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
				Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(44.9)%-58.9%
Total CECONY—Commodity		$—

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

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

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of September 30, 2016 and 2015 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016		2015
Beginning balance as of July 1,	$5	$13	$2		$11
Included in earnings	(4)	(4)	—		(1)
Included in regulatory assets and liabilities	(5)	(1)	(3)		(1)
Purchases	—	1	—		1
Sales (a)	4	—	—		—
Settlements	1	(5)	1		(2)
Ending balance as of September 30,	$1	$4		$—	$8

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	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016		2015
Beginning balance as of January 1,	$6	$20	$8		$13
Included in earnings	(1)	(18)	(1)		(5)
Included in regulatory assets and liabilities	(11)	(1)	(6)		(1)
Purchases	2	9	1		5
Sales (a)	4	—	—		—
Settlements	1	(6)	(2)		(4)
Ending balance as of September 30,	$1	$4		$—	$8

(a) Amounts represent derivative instruments novated as part of the assets of Con Edison Solutions’ retail electric supply business which were sold to a subsidiary of Exelon Corporation (see Note P).

For the Utilities, realized gains and losses on Level 3 commodity derivative assets and liabilities are reported as part of purchased power, gas and fuel costs. The Utilities generally recover these costs in accordance with rate provisions approved by the applicable state public utilities regulators. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations.

For the competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues (immaterial for both periods) and purchased power costs ($5 millionloss and $3 millionloss) on the consolidated income statement for the three months ended September 30, 2016 and 2015, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues (immaterial for both periods) and purchased power costs ($6 millionloss and $12 millionloss) on the consolidated income statement for the nine months ended September 30, 2016, and 2015, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at September 30, 2016 and 2015 is included in non-utility revenues (immaterial for both periods) and purchased power costs ($4 millionloss and $3 millionloss) on the consolidated income statement for the three months ended September 30, 2016 and 2015, respectively. For the nine months ended September 30, 2016, and 2015, the change in fair value relating to Level 3 commodity derivative assets and liabilities is included in non-utility revenues (immaterial for both periods) and purchased power costs ($2 millionloss and $8 millionloss) 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 had a variable interest in a non-consolidated variable interest entity (VIE), Astoria Energy, LLC (Astoria Energy), with which CECONY entered into a long-term electricity purchase agreement that expired in April 2016. CECONY has ongoing long-term electricity purchase agreements with the following two potential VIEs: Cogen Technologies Linden Venture, LP, and Brooklyn Navy Yard Cogeneration Partners, LP. In 2015, requests were made of these two counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. The payments for these contracts constitute CECONY’s maximum exposure to loss with respect to the potential VIEs.

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

Project Name (a)	Generating Capacity (b) (MW AC)	Power Purchase Agreement Term (in Years)	Year of Initial Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (c)
Copper Mountain Solar 3	128	20	2014	Nevada	$179
Panoche Valley (d)	120	20	2015	California	274
Mesquite Solar 1	83	20	2013	Arizona	107
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	70
Broken Bow II	38	25	2014	Nebraska	51
Texas Solar 4	32	25	2014	Texas	43

(a) With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development. The maximum exposure for Texas Solar 4 is the net assets of the investment offset by an $8 million noncontrolling interest.

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

(c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet and any related receivables due from the project. For consolidated investments, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

(d) In October 2016, Con Edison Development acquired the remaining 50 percent ownership interest in the project. See Note P.

Note N — Related Party Transactions

The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric has a 45.7 percent equity interest (see Note P). The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the three and nine months ended September 30, 2016, the amounts billed by CECONY to NY Transco were immaterial.

CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC (Stagecoach), a joint venture formed by a subsidiary of CET Gas and a subsidiary of Crestwood Equity Partners LP (Crestwood) (see Note P). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. For the three months ended September 30, 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $8 million. Since the formation of the joint venture in June 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $10 million.

CECONY has a financial electric capacity contract with Con Edison Energy for the period May 2016 through April 2017. For the three and nine months ended September 30, 2016, Con Edison Energy's realized losses under this contract were $1 million.

At September 30, 2016 Con Edison Development has an outstanding note receivable of $234 million from Panoche Valley, a solar electric production project in which Con Edison Development has an ownership interest of 50 percent (see Note M). In October 2016, Con Edison Development acquired the remaining 50 percent interest in the project (see Note P).

Note O — New Financial Accounting Standards

In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board jointly issued a revenue recognition standard that will supersede the revenue recognition requirements within Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. Additionally, in March and April 2016, respectively, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations (Reporting Revenue Gross Versus Net)” to clarify how to apply the implementation guidance for principal versus agent considerations and ASU No. 2016-10,“Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing”

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to clarify the guidance pertaining to identifying performance obligations and licensing implementation guidance. Furthermore in May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” to clarify assessing collectibility, presentation of sales taxes, noncash consideration, contract modification at transition, and completed contracts at transition. The new standard is effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for reporting periods beginning after December 15, 2016. The Companies are in the process of evaluating the application and impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The

Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” This amendment requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments in this Update are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements

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to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of the 2014-09 and 2014-16. The Companies are in the process of evaluating the potential impact of the amendments on the Companies’ financial position, results of operations and liquidity.

In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial

instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In August 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force).” The amendment specifies the classification and presentation of certain cash flow items to reduce diversity in practice. 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 October 2016, the FASB issued amendments to the guidance for Income Taxes through ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory.” The amendment clarifies the tax treatment of intra-entity transfers of assets other than inventory. The updated guidance requires entities recognize the income tax consequences of an intra-entity transfer of assets other than inventory when the transfer occurs. 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 P — Acquisitions, Investments and Dispositions

Acquisitions and Investments

Texas Solar 7

In January 2016, Con Edison Development acquired a 100 percent interest in a company that is the owner of a 106 MW (AC) solar electric production project in Texas (Texas Solar 7) for $227 million; $218 million was recorded as non-utility construction work in progress and the remaining $9 million was recorded as other receivables. At September 30, 2016 net assets of the project are approximately $123 million. The project has been financed, in part, by debt secured by the project (see Note C). Electricity generated by this project is to be purchased by the City of San Antonio pursuant to a long-term power purchase agreement. The project commenced commercial operation in the third quarter of 2016. Con Edison's interest in Texas Solar 7 is consolidated in the financial statements.

Mountain Valley Pipeline

In January 2016, CET Gas acquired a 12.5 percent equity interest in Mountain Valley Pipeline, LLC (MVP), a company developing a proposed gas transmission project in West Virginia and Virginia. The company's initial contribution to MVP was $18 million. At September 30, 2016, CET Gas' investment in MVP was $41 million. The estimated total project cost is $3,000 million to $3,500 million. Subject to FERC approval, MVP is targeting to be fully in-service during 2018. Con Edison is accounting for its equity interest in MVP as an equity method investment.

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Stagecoach Gas Services

In April 2016, a CET Gas subsidiary agreed with a subsidiary of Crestwood to form a joint venture to own, operate and further develop existing natural gas pipeline and storage businesses located in northern Pennsylvania and southern New York. The transaction was substantially completed during June 2016. Crestwood contributed businesses to a new entity, Stagecoach, and the CET Gas subsidiary purchased a 50 percent equity interest in Stagecoach for $945 million (subject to closing adjustments). At September 30, 2016, CET Gas' investment in Stagecoach was $968 million. Con Edison is accounting for its equity interest in Stagecoach as an equity method investment.

NY Transco

In January 2016, CECONY entered into an agreement to transfer certain electric transmission projects to NY Transco, a company in which CET Electric has a 45.7 percentequity interest. In April 2016, the NYSPSC authorized CECONY, subject to certain conditions, to transfer the projects to NY Transco. In May 2016, CECONY transferred the projects to NY Transco for a purchase price of $122 million and an $8 million payment for easement rights on certain associated property. At September 30, 2016, CET Electric's investment in NY Transco was $53 million. Con Edison is accounting for its equity interest in NY Transco as an equity method investment.

Pilesgrove

In June 2016, Con Edison Development recorded an $8 million ($5 million, net of taxes) impairment charge on its 50 percent interest in Pilesgrove Solar, LLC (Pilesgrove), which owns an 18 MW (AC) solar electric production project in New Jersey. In August 2016, Con Edison Development acquired the remaining 50 percent interest in Pilesgrove for a purchase price of approximately $16 million and recorded a bargain purchase gain of $8 million ($5 million, net of taxes). The impairment charge and bargain purchase gain are included in Investment and other income on Con Edison’s consolidated income statement. Con Edison's interest in Pilesgrove is consolidated in the financial statements subsequent to the August 2016 acquisition. At September 30, 2016, net assets of the project are approximately $48 million, consisting primarily of $45 million recorded as non-utility property and $3 million recorded in current assets.

Panoche Valley

In October 2016, Con Edison Development acquired the remaining 50 percent interest in Panoche Holdings, LLC, which is developing a 240 MW (AC) solar electric production project in California, for cash consideration of $37 million, net of applicable purchase price adjustments. Con Edison will consolidate the project on its financial statements as of the date of acquisition. See Note M.

Dispositions

Pike County Light & Power Company (Pike)

In October 2015, upon evaluating strategic alternatives, O&R entered into an agreement to sell Pike to Corning Natural Gas Holding Corporation (Corning). In August 2016, the sale was completed. O&R received cash consideration of $15 million for the sale. O&R has agreed to provide transition services to Corning for operations and customer support for a period of up to 18 months subsequent to the sale. In addition, O&R will continue to purchase and sell to Pike electric and gas commodity for three years. Pike has an option to extend the service for up to an additional three years.

At September 30, 2015, O&R recorded an impairment charge of $5 million ($3 million, net of taxes), representing the difference between the carrying amount of Pike’s assets and the estimated sales proceeds. At December 31, 2015, Pike’s total assets and liabilities held for sale were $23 million and $5 million, respectively. There were no amounts outstanding at September 30, 2016.

Con Edison Solutions' Retail Electric Supply Business

In July 2016, Con Edison Solutions entered into an agreement to sell the assets of its retail electric supply business (including retail contracts, related derivative instruments, information systems, and accounts receivable) to a subsidiary of Exelon Corporation (Exelon). In September 2016, the sale was completed for cash consideration of $235 million, subject to working capital adjustments. The sale resulted in a gain of $104 million ($47 million, net of taxes), inclusive of a $65 million ($42 million, net of taxes) gain on derivative instruments. The tax effect of the sale includes $29 million ($19 million, net of federal tax) of state taxes related to a change in the apportionment of state income taxes. Con Edison Solutions has agreed to provide transition services to the Exelon subsidiary for operations and customer support through the end of 2017 during which period certain guarantees or other credit support provided by Con Edison in connection with the retail electric supply business may continue in effect. See

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Note H. At December 31, 2015, Con Edison Solutions' total assets and liabilities held for sale were $134 million and $84 million, respectively. There were no amounts outstanding at September 30, 2016.

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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 Third 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 Third 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, 2015 (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 Reports on Form 10-Q for the quarterly periods ended March 31,2016 and June 30, 2016 (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), the competitive energy businesses and Con Edison Transmission, Inc. (Con Edison Transmission). 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 competitive 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 competitive energy businesses provide energy-related products and services, and develop, own and operate renewable and energy infrastructure projects. 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.

During the summer of 2016, electric peak demand in the company's service area was 12,652 MW (which occurred on August 11, 2016). At design conditions, electric peak demand in the company's service area would have been approximately 13,450 MW in 2016 compared to the company's forecast of 13,650 MW. The company's five-year forecast of average annual growth of the electric peak demand in its service area at design conditions is approximately 0.2 percent for 2017 to 2021 (the same as its forecast for 2016 to 2020).

Gas

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

Steam

CECONY operates the largest steam distribution system in the United States by producing and delivering approximately 22,000 MMlb of steam annually to approximately 1,700 customers in parts of Manhattan.

Collective Bargaining Agreement

In June 2016, CECONY reached a four-year collective bargaining agreement with its largest union covering approximately 8,000 employees, effective June 26, 2016.

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 in northern New Jersey, an approximately 1,300 square mile service area.

During the summer of 2016, electric peak demand in the company's service area was 1,435 MW (which occurred on July 22, 2016). At design conditions, electric peak demand in the company's service area would have been approximately 1,615 MW in 2016 compared to the company's forecast of 1,632 MW. The company decreased its five-year forecast of average annual growth of the electric peak demand in its service area at design conditions from approximately 0.3 percent (for 2016 to 2020) to (0.1) percent (for 2017 to 2021) primarily due to a forecasted increase in distributed generation (photovoltaic) as well as lower growth in demand from customers.

Gas

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

Sale of Pike County Light & Power Company (Pike)

In August 2016, O&R sold its Pennsylvania subsidiary, Pike, to Corning Natural Gas Holding Corporation (see Note P to the Third Quarter Financial Statements).

Competitive Energy Businesses

Con Edison pursues competitive energy opportunities through three wholly-owned subsidiaries: Con Edison Solutions, Con Edison Energy and Con Edison Development. These businesses provide energy-related products and services to wholesale and retail customers, and develop, own and operate renewable and energy infrastructure projects.

Sale of the Retail Electric Supply Business

In September 2016, Con Edison sold the retail electric supply business of its competitive energy businesses to a subsidiary of Exelon Corporation (see Note P to the Third Quarter Financial Statements).

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Con Edison Transmission

Con Edison Transmission 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 (formerly known as Con Edison Gas Midstream, LLC, CET Gas). CET Electric, which was formed in 2014, is investing in a company that owns electric transmission assets in New York. CET Gas, which was formed in 2016, owns, through a subsidiary, a 50 percent equity 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. In addition, CET Gas owns a 12.5 percent equity interest in a company developing a proposed gas transmission project in West Virginia and Virginia. See “Con Edison Transmission,” below.

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

	For the Three Months Ended September 30, 2016						For the Nine Months Ended September 30, 2016						At September 30, 2016
(Millions of Dollars, except percentages)	Operating Revenues			Net Income			Operating Revenues			Net Income			Assets
CECONY	$2,828	83	%	$388	78	%	$7,741	82	%	$859	83	%	$40,436	85	%
O&R	240	7		27	5		630	7		55	5		2,784	6
Total Utilities	3,068	90		415	83		8,371	89		914	88		43,220	91
Competitive energy businesses (a)	350	10		78	16		998	11		120	12		2,394	5
Con Edison Transmission	—	—		10	2		—	—		11	1		1,072	2
Other (b)	(1)	—		(6)	(1	)	(1)	—		(6)	(1	)	630	2
Total Con Edison	$3,417	100	%	$497	100	%	$9,368	100	%	$1,039	100	%	$47,316	100	%

(a) Net income from the competitive energy businesses for the three and nine months ended September 30, 2016 includes $47 million of net gain related to the sale of the retail electric supply business, $5 million of net gain related to the acquisition of a solar electric production investment and for the nine months ended September 30, 2016 includes $5 million of net loss related to the impairment of a solar electric production investment (see Note P to the Third Quarter Financial Statements). Also includes for the three and nine months ended September 30, 2016$(15) million and $5 million, respectively, of net after-tax mark-to-market gains/(losses).

(b) Other includes parent company and consolidation adjustments.

Results of Operations

Net income and earnings per share for the three and nine months ended September 30, 2016 and 2015 were as follows:

	For the Three Months Ended September 30,								For the Nine Months Ended September 30,
	2016	2015	2016			2015			2016	2015	2016			2015
(Millions of Dollars, except per share amounts)	Net Income		Earnings per Share						Net Income		Earnings per Share
CECONY	$388	$375		$1.27			$1.28		$859	$935		$2.87			$3.19
O&R (a)	27	20	0.09			0.07			55	35	0.18			0.12
Competitive energy businesses (b)	78	37	0.26			0.12			120	55	0.40			0.19
Con Edison Transmission	10	—	0.03			—			11	—	0.04			—
Other (c)	(6)	(4)	(0.02		)	(0.01		)	(6)	(8)	(0.02		)	(0.03		)
Con Edison (d)	$497	$428		$1.63			$1.46		$1,039	$1,017		$3.47			$3.47

(a) Includes $3 million or $0.01 a share of net loss for the three and nine months ended September 30, 2015 related to the impairment of certain assets held for sale (see Note P to the Third Quarter Financial Statements).

(b) Includes $47 million or $0.15 a share of net gain related to the sale of the retail electric supply business, $5 million or $0.02 a share of net gain related to the acquisition of a solar electric production investment for the three and nine months ended September 30, 2016 and $5 million and or $0.02 a share of net loss related to the impairment of a solar electric production investment for the nine months ended September 30, 2016 (see Note P to the Third Quarter Financial Statements). Also includes $(15) million or $(0.05) a share and $7 million or $0.02 a share of net after-tax mark-to-market gains/(losses) for the three months ended September 30, 2016 and 2015, respectively, and $5 million or $0.02 a share and $2 million or $0.01 a share of net after-tax mark-to-market gains for the nine months ended September 30, 2016 and 2015, respectively.

(c) Other includes parent company and consolidation adjustments.

(d) Earnings per share on a diluted basis were $1.62 a share and $1.45 a share for the three months ended September 30, 2016 and 2015, respectively, and $3.46 a share for the nine months ended September 30, 2016 and 2015.

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The Companies’ results of operations for the three and nine months ended September 30, 2016, as compared with the 2015 periods, reflect changes in rate plans and regulatory charges and, in the nine month period, the impact of warmer than normal weather on steam revenues. Other lower operations and maintenance expenses reflect lower surcharges for assessments and fees that are collected in revenues from customers at the Utilities. In the nine month period, these expenses also reflect higher expenses for emergency response, municipal infrastructure support and stock-based compensation at CECONY. In addition, the Utilities' 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 higher electric retail gross profit and income from renewable investments, the gain on sale of retail electric supply business, the gain and impairment related to a solar electric production investment, and the impact of the net mark-to-market effects of the competitive energy businesses.

The following table presents the estimated effect on earnings per share and net income for the three and nine months ended September 30, 2016 period as compared with 2015 periods, resulting from these and other major factors:

	Three Months Variation		Nine 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	$0.05	$16	$0.14		$40
Weather impact on steam revenues	—	1	(0.12)		(36)
Other operations and maintenance expenses	0.05	16	0.07		21
Depreciation, property taxes and other tax matters	(0.06)	(18)	(0.30)		(88)
Other (b)	(0.05)	(2)	(0.11)		(13)
Total CECONY	(0.01)	13	(0.32)		(76)
O&R (a)
Changes in rate plans and regulatory charges	0.02	5	0.02		7
Other operations and maintenance expenses	0.01	3	0.06		17
Depreciation and property taxes	(0.01)	(3)	(0.03)		(8)
Other (c)	—	2	0.01		4
Total O&R	0.02	7	0.06		20
Competitive energy businesses
Operating revenues less energy costs	(0.02)	(7)	0.14		41
Other operations and maintenance expenses	—	(2)	(0.05)		(16)
Gain on sale of retail electric supply business	0.15	47	0.15		47
Other (b)	0.01	3	(0.03)		(7)
Total competitive energy businesses (c)	0.14	41	0.21		65
Con Edison Transmission	0.03	10	0.04		11
Other, including parent company expenses	(0.01)	(2)	0.01		2
Total variations	$0.17	$69		$—	$22

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

(c) These variations include the impairment of certain assets held for sale in 2015, the gain and impairment related to a solar electric production investment and net mark-to-market effects shown in notes (a) and (b) in the Results of Operations table above.

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The Companies’ other operations and maintenance expenses for the three and nine months ended September 30, 2016 and 2015 were as follows:

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars)	2016	2015	2016	2015
CECONY
Operations	$381	$383	$1,109	$1,074
Pensions and other postretirement benefits	87	91	261	273
Health care and other benefits	44	38	122	116
Regulatory fees and assessments (a)	129	153	346	433
Other	83	85	267	244
Total CECONY	724	750	2,105	2,140
O&R	77	82	220	249
Competitive energy businesses	40	37	124	98
Con Edison Transmission	1	—	1	—
Other (b)	(2)	—	(3)	(2)
Total other operations and maintenance expenses	$840	$869	$2,447	$2,485

(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.

Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, Con Edison’s competitive energy businesses and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. A discussion of the results of operations by principal business segment for the three and nine months ended September 30, 2016 and 2015 follows. For additional business segment financial information, see Note J to the Third Quarter Financial Statements.

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Three Months Ended September 30, 2016 Compared with Three Months Ended September 30, 2015

The Companies’ results of operations in 2016 compared with 2015 were:

	CECONY			O&R			Competitive 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	$(1)	—	%	$11	4.8	%	$(36)	(9.3	)%		$—	—	%		$—	—%		$(26)	(0.8	)%
Purchased power	(31)	(5.9	)	5	7.8		(36)	(13.3	)	—		—		—		—		(62)	(7.2	)
Fuel	(2)	(6.5	)	—	—		—	—		—		—		—		—		(2)	(6.5	)
Gas purchased for resale	4	13.3		(1)	(11.1	)	14	56.0		—		—		—		—		17	26.6
Other operations and maintenance	(26)	(3.5	)	(5)	(6.1	)	3	8.1		1		—		(2)		—		(29)	(3.3	)
Depreciation and amortization	16	6.1		—	—		5	83.3		—		—		(1)		—		20	7.0
Taxes, other than income taxes	17	3.5		6	40.0		—	—		—		—		1		Large		24	4.8
Gain on sale of retail electric supply business	—	—		—	—		104	—		—		—		—		—		104	—
Operating income	21	2.8		6	14.3		82	Large		(1)		—		2		—		110	13.3
Other income less deductions	5	Large		6	Large		10	58.8		20		—		(1)		—		40	Large
Net interest expense	9	6.2		—	—		5	Large		3		—		(1)		(16.7	)	16	9.9
Income before income tax expense	17	2.8		12	42.9		87	Large		16		—		2		33.3		134	19.8
Income tax expense	4	1.8		5	62.5		46	Large		6		—		4		Large		65	26.1
Net income	$13	3.5	%	$7	35.0	%	$41	Large		$10		—	%	$(2)		(50.0	)%	$69	16.1	%

(a) Includes parent company and consolidation adjustments.

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

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CECONY

	For the Three Months Ended September 30, 2016				For the Three Months Ended September 30, 2015
(Millions of Dollars)	Electric	Gas	Steam	2016 Total	Electric	Gas	Steam	2015 Total	2016-2015 Variation
Operating revenues	$2,557	$208	$63	$2,828	$2,558	$213	$58	$2,829	$(1)
Purchased power	486	—	9	495	519	—	7	526	(31)
Fuel	21	—	8	29	24	—	7	31	(2)
Gas purchased for resale	—	34	—	34	—	30	—	30	4
Other operations and maintenance	578	102	44	724	598	106	46	750	(26)
Depreciation and amortization	217	41	20	278	207	35	20	262	16
Taxes, other than income taxes	414	59	29	502	399	59	27	485	17
Operating income	$841	$(28)	$(47)	$766	$811	$(17)	$(49)	$745	$21

Electric

CECONY’s results of electric operations for the three months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$2,557	$2,558	$(1)
Purchased power	486	519	(33)
Fuel	21	24	(3)
Other operations and maintenance	578	598	(20)
Depreciation and amortization	217	207	10
Taxes, other than income taxes	414	399	15
Electric operating income	$841	$811	$30

CECONY’s electric sales and deliveries for the three months ended September 30, 2016 compared with the 2015 period were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Three Months Ended						For the Three Months Ended
Description	September 30, 2016	September 30, 2015	Variation	Percent Variation			September 30, 2016	September 30, 2015	Variation	Percent Variation
Residential/Religious (b)	3,653	3,577	76	2.1	%		$883	$903	$(20)	(2.2	)%
Commercial/Industrial	2,749	2,692	57	2.1			551	574	(23)	(4.0	)
Retail choice customers	8,136	7,822	314	4.0			918	888	30	3.4
NYPA, Municipal Agency and other sales	2,764	2,731	33	1.2			204	198	6	3.0
Other operating revenues (c)	—	—	—	—			1	(5)	6	Large
Total	17,302	16,822	480	2.9	%	(d)	$2,557	$2,558	$(1)	—	%

(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, principally weather and billing days, electric delivery volumes in CECONY’s service area increased 1.0 percent in the three months ended September 30, 2016 compared with the 2015 period.

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Operating revenuesdecreased$1 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to lower purchased power costs ($33 million) and fuel expenses ($3 million), offset in part by higher revenues from the electric rate plan ($35 million).

Purchased power expenses decreased$33 million in the three months ended September 30, 2016 compared with the 2015 period due to lower unit costs ($39 million), offset by higher purchased volumes ($6 million).

Fuel expenses decreased$3 million in the three months ended September 30, 2016 compared with the 2015 period due to lower unit costs.

Other operations and maintenance expenses decreased$20 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to a decrease in the surcharges for assessments and fees that are collected in revenues from customers.

Depreciation and amortizationincreased$10 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher electric utility plant balances.

Taxes, other than income taxesincreased$15 million in the three months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes ($13 million) and state and local taxes ($2 million).

Gas

CECONY’s results of gas operations for the three months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$208	$213	$(5)
Gas purchased for resale	34	30	4
Other operations and maintenance	102	106	(4)
Depreciation and amortization	41	35	6
Taxes, other than income taxes	59	59	—
Gas operating income	$(28)	$(17)	$(11)

CECONY’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, 2016 compared with the 2015 period were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016	September 30, 2015	Variation	Percent Variation
Residential	4,335	4,118	217		5.3	%		$88	$83	$5	6.0	%
General	3,963	3,226	737		22.8			41	35	6	17.1
Firm transportation	8,305	8,185	120		1.5			53	58	(5)	(8.6	)
Total firm sales and transportation	16,603	15,529	1,074		6.9		(b)	182	176	6	3.4
Interruptible sales (c)	1,664	1,772	(108	)	(6.1	)		4	6	(2)	(33.3	)
NYPA	12,800	14,023	(1,223	)	(8.7	)		1	1	—	—
Generation plants	35,745	30,610	5,135		16.8			7	7	—	—
Other	4,975	4,512	463		10.3			6	6	—	—
Other operating revenues (d)	—	—	—		—			8	17	(9)	(52.9	)
Total	71,787	66,446	5,341		8.0	%		$208	$213	$(5)	(2.3	)%

(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, principally billing days, firm gas sales and transportation volumes in the company’s service area increased 7.8 percent in the three months ended September 30, 2016 compared with the 2015 period, reflecting primarily increased volumes attributable to additional customers that have converted from oil-to-gas as heating fuel for their buildings.

(c) Includes 915 thousands and 765 thousands of Dt for the 2016 and 2015 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 revenuesdecreased$5 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to changes in regulatory charges ($12 million), offset in part by higher gas purchased for resale expense ($4 million).

Gas purchased for resaleincreased$4 million in the three months ended September 30, 2016 compared with the 2015 period due to higher unit costs ($7 million), offset by lower sendout volumes ($3 million).

Other operations and maintenance expenses decreased$4 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to a decrease in the surcharges for assessments and fees that are collected in revenues from customers ($2 million) and lower stock-based compensation costs ($2 million).

Depreciation and amortizationincreased$6 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher gas utility plant balances.

Steam

CECONY’s results of steam operations for the three months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$63	$58	$5
Purchased power	9	7	2
Fuel	8	7	1
Other operations and maintenance	44	46	(2)
Depreciation and amortization	20	20	—
Taxes, other than income taxes	29	27	2
Steam operating income	$(47)	$(49)	$2

CECONY’s steam sales and deliveries for the three months ended September 30, 2016 compared with the 2015 period were:

	Millions of Pounds Delivered							Revenues in Millions
	For the Three Months Ended							For the Three Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016	September 30, 2015	Variation		Percent Variation
General	10	19	(9	)	(47.4	)%		$2	$2		$—	—	%
Apartment house	776	816	(40	)	(4.9	)		15	16	(1)		(6.3	)
Annual power	2,950	2,961	(11	)	(0.4	)		49	46	3		6.5
Other operating revenues (a)	—	—	—		—			(3)	(6)	3		50.0
Total	3,736	3,796	(60	)	(1.6	)%	(b)	$63	$58	$5		8.6	%

(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, principally weather and billing days, steam sales and deliveries decreased 3.4 percent in three months ended September 30, 2016 compared with the 2015 period.

Operating revenuesincreased$5 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher revenues from the steam rate plan ($3 million), purchased power costs ($2 million) and fuel expenses ($1 million).

Purchased power expenses increased$2 million in the three months ended September 30, 2016 compared with the 2015 period due to higher unit costs.

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Fuel expenses increased$1 million in the three months ended September 30, 2016 compared with the 2015 period due to higher unit costs.

Other operations and maintenance expenses decreased$2 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to lower stock-based compensation costs.

Taxes, other than income taxesincreased$2 million in the three months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes.

Net Interest Expense

Net interest expense increased $9 million in the three months ended September 30, 2016 compared with the 2015 period due primarily higher long-term debt balances in the 2016 period.

Income Tax Expense

Income taxes increased $4 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher income before income tax expense ($7 million) and plant-related flow through items ($13 million), offset in part by lower state income taxes ($8 million), a research and development tax credit ($5 million) and higher settlement payments related to injuries and damages ($2 million).

O&R

	For the Three Months Ended September 30, 2016			For the Three Months Ended September 30, 2015
(Millions of Dollars)	Electric	Gas	2016 Total	Electric	Gas	2015 Total	2016-2015 Variation
Operating revenues	$213	$27	$240	$205	$24	$229	$11
Purchased power	69	—	69	64	—	64	5
Gas purchased for resale	—	8	8	—	9	9	(1)
Other operations and maintenance	63	14	77	66	16	82	(5)
Depreciation and amortization	12	5	17	13	4	17	—
Taxes, other than income taxes	14	7	21	11	4	15	6
Operating income	$55	$(7)	$48	$51	$(9)	$42	$6

Electric

O&R’s results of electric operations for the three months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$213	$205	$8
Purchased power	69	64	5
Other operations and maintenance	63	66	(3)
Depreciation and amortization	12	13	(1)
Taxes, other than income taxes	14	11	3
Electric operating income	$55	$51	$4

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O&R’s electric sales and deliveries for the three months ended September 30, 2016 compared with the 2015 period were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016	September 30, 2015	Variation		Percent Variation
Residential/Religious (b)	585	533	52		9.8	%		$109	$99	$10		10.1	%
Commercial/Industrial	216	220	(4	)	(1.8	)		35	35	—		—
Retail choice customers	925	926	(1	)	(0.1	)		70	69	1		1.4
Public authorities	31	28	3		10.7			2	3	(1	)	(33.3	)
Other operating revenues (c)	—	—	—		—			(3)	(1)	(2)		Large
Total	1,757	1,707	50		2.9	%	(d)	$213	$205	$8		3.9	%

(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 and Pennsylvania 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 plans.

(d) After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased 0.9 percent in the three months ended September 30, 2016 compared with the 2015 period.

Operating revenuesincreased$8 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher revenues from the electric rate plans ($6 million) and purchased power costs ($5 million).

Purchased power expenses increased$5 million in the three months ended September 30, 2016 compared with the 2015 period due to higher purchased volumes ($6 million), offset by lower unit costs ($1 million).

Other operations and maintenance expenses decreased$3 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to regulatory accounting effects of pension costs.

Depreciation and amortizationdecreased$1 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to lower average depreciation rates.

Taxes, other than income taxesincreased$3 million in the three months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes.

Gas

O&R’s results of gas operations for the three months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$27	$24	$3
Gas purchased for resale	8	9	(1)
Other operations and maintenance	14	16	(2)
Depreciation and amortization	5	4	1
Taxes, other than income taxes	7	4	3
Gas operating income	$(7)	$(9)	$2

54

O&R’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, 2016 compared with the 2015 period were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016	September 30, 2015	Variation	Percent Variation
Residential	550	481	69		14.3	%		$9	$7	$2	28.6	%
General	177	120	57		47.5			2	1	1	Large
Firm transportation	884	980	(96	)	(9.8	)		8	8	—	—
Total firm sales and transportation	1,611	1,581	30		1.9		(b)	19	16	3	18.8
Interruptible sales	893	938	(45	)	(4.8	)		—	—	—	—
Generation plants	3	10	(7	)	(70.0	)		—	—	—	—
Other	70	70	—		—			—	—	—	—
Other gas revenues	—	—	—		—			8	8	—	—
Total	2,577	2,599	(22	)	(0.8	)%		$27	$24	$3	12.5	%

(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 1.7 percent in the three months ended September 30, 2016 compared with 2015 period.

Operating revenuesincreased$3 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher revenues from the New York gas rate plan ($4 million), offset by a decrease in gas purchased for resale ($1 million).

Gas purchased for resaledecreased$1 million in the three months ended September 30, 2016 compared with the 2015 period due to lower purchased volumes ($2 million), offset by higher unit costs ($1 million).

Other operations and maintenance expenses decreased$2 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to regulatory accounting effects of pension costs.

Depreciation and amortizationincreased$1 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher gas utility plant balances.

Taxes, other than income taxesincreased$3 million in the three months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes.

Other Income (Deductions)

Other income (deductions) increased$6 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to the impairment of certain assets held for sale in 2015 (see Note P to the Third Quarter Financial Statements).

Income Tax Expense

Income taxes increased $5 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher income before income tax expense.

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Competitive Energy Businesses

The competitive energy businesses’ results of operations for the three months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$350	$386	$(36)
Purchased power	234	270	(36)
Gas purchased for resale	39	25	14
Other operations and maintenance	40	37	3
Depreciation and amortization	11	6	5
Taxes, other than income taxes	5	5	—
Gain on sale of retail electric supply business	(104)	—	(104)
Operating income	$125	$43	$82

Operating revenuesdecreased$36 million in the three months ended September 30, 2016 compared with the 2015 period, due primarily to lower electric retail revenues due in part to the sale of the retail electric supply business (see Note P to the Third Quarter Financial Statements). Electric retail revenues decreased $71 million due to lower sales volume ($57 million) and unit prices ($14 million). Renewable revenues increased $15 million primarily due to an increase in renewable electric production projects in operation. Energy services revenues increased $9 million. Wholesale revenues increased $12 million due to higher sales volumes. Net mark-to-market values decreased $36 million, of which $35 million in losses are reflected in purchased power costs and $1 million in losses are reflected in revenues.

Purchased power expenses decreased$36 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to lower volumes ($51 million) and lower unit prices ($20 million), offset by changes in mark-to-market losses ($35 million).

Gas purchased for resaleincreased$14 million in the three months ended September 30, 2016 compared with the 2015 period due to higher sale volumes.

Other operations and maintenance expenses increased$3 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to an increase in energy services costs.

Depreciation and amortizationincreased$5 million in the three months ended September 30, 2016 compared with the 2015 period due an increase in solar electric production projects in operation during 2016.

Gain on sale of retail electric supply business was $104 million in the three months ended September 30, 2016 reflecting the sale of the competitive energy businesses' retail electric supply business (see Note P to the Third Quarter Financial Statements).

Other Income (Deductions)

Other income (deductions) increased$10 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to the gain related to the acquisition of a solar electric production investment (see Note P to the Third Quarter Financial Statements).

Net Interest Expense

Net interest expense increased$5 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to increased debt on solar projects.

Income Tax Expense

Income taxes increased$46 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to higher income before income tax expense ($35 million) and an adjustment to deferred state income taxes as a result of the sale of the retail electric supply business that increased the competitive energy businesses'

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state apportionment factors on its cumulative temporary differences ($13 million), offset in part by higher renewable energy tax credits ($2 million).

Con Edison Transmission

Other Income (Deductions)

Other income (deductions) increased $20 million in the three months ended September 30, 2016 compared with the 2015 period due primarily to earnings from equity investments in 2016 (see Note P).

Other

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

57

Nine Months Ended September 30, 2016 Compared with Nine Months Ended September 30, 2015

The Companies’ results of operations in 2016 compared with 2015 were:

	CECONY			O&R			Competitive 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	$(381)	(4.7	)%	$(10)	(1.6	)%	$(89)	(8.2	)%		$—	—	%	$1	50.0	%	$(479)	(4.9	)%
Purchased power	(207)	(14.5	)	(15)	(8.9	)	(136)	(16.7	)	—		—		1	—		(357)	(14.9	)
Fuel	(83)	(38.4	)	—	—		—	—		—		—		—	—		(83)	(38.4	)
Gas purchased for resale	(65)	(23.0	)	(8)	(20.0	)	(22)	(23.4	)	—		—		—	—		(95)	(22.9	)
Other operations and maintenance	(35)	(1.6	)	(29)	(11.6	)	26	26.5		1		—		(1)	(50.0	)	(38)	(1.5	)
Depreciation and amortization	52	6.7		(1)	(2.0	)	14	87.5		—		—		—	—		65	7.7
Taxes, other than income taxes	47	3.4		14	30.4		2	14.3		—		—		1	—		64	4.4
Gain on sale of retail electric supply business	—	—		—	—		104	—		—		—		—	—		104	—
Operating income	(90)	(4.8	)	29	34.1		131	Large		(1)		—		—	—		69	3.4
Other income less deductions	6	Large		5	Large		3	9.4		23		—		1	Large		38	Large
Net interest expense	16	3.7		1	3.7		18	Large		4		—		(8)	(42.1	)	31	6.4
Income before income tax expense	(100)	(6.9	)	33	61.1		116	Large		18		—		9	47.4		76	4.9
Income tax expense	(24)	(4.7	)	13	68.4		51	Large		7		—		7	63.6		54	9.9
Net income	$(76)	(8.1	)%	$20	57.1	%	$65	Large		$11		—	%	$2	25.0	%	$22	2.2	%

(a) Includes parent company and consolidation adjustments.

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

58

CECONY

	For the Nine Months Ended September 30, 2016				For the Nine Months Ended September 30, 2015
(Millions of Dollars)	Electric	Gas	Steam	2016 Total	Electric	Gas	Steam	2015 Total	2016-2015 Variation
Operating revenues	$6,222	$1,113	$406	$7,741	$6,416	$1,177	$529	$8,122	$(381)
Purchased power	1,191	—	25	1,216	1,395	—	28	1,423	(207)
Fuel	81	—	52	133	96	—	120	216	(83)
Gas purchased for resale	—	217	—	217	—	282	—	282	(65)
Other operations and maintenance	1,659	307	139	2,105	1,677	323	140	2,140	(35)
Depreciation and amortization	645	118	62	825	610	105	58	773	52
Taxes, other than income taxes	1,159	198	89	1,446	1,127	189	83	1,399	47
Operating income	$1,487	$273	$39	$1,799	$1,511	$278	$100	$1,889	$(90)

Electric

CECONY’s results of electric operations for the nine months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$6,222	$6,416	$(194)
Purchased power	1,191	1,395	(204)
Fuel	81	96	(15)
Other operations and maintenance	1,659	1,677	(18)
Depreciation and amortization	645	610	35
Taxes, other than income taxes	1,159	1,127	32
Electric operating income	$1,487	$1,511	$(24)

CECONY’s electric sales and deliveries for the nine months ended September 30, 2016 compared with the 2015 period were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016	September 30, 2015	Variation	Percent Variation
Residential/Religious (b)	8,130	8,247	(117	)	(1.4	)%		$2,017	$2,198	$(181)	(8.2	)%
Commercial/Industrial	7,220	7,375	(155	)	(2.1	)		1,381	1,549	(168)	(10.8	)
Retail choice customers	20,404	20,339	65		0.3			2,114	2,102	12	0.6
NYPA, Municipal Agency and other sales	7,641	7,687	(46	)	(0.6	)		474	467	7	1.5
Other operating revenues (c)	—	—	—		—			236	100	136	Large
Total	43,395	43,648	(253	)	(0.6	)%	(d)	$6,222	$6,416	$(194)	(3.0	)%

(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, principally weather and billing days, electric delivery volumes in CECONY’s service area increased 0.5 percent in the nine months ended September 30, 2016 compared with the 2015 period.

59

Operating revenuesdecreased$194 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to lower purchased power costs ($204 million) and fuel expenses ($15 million), offset in part by changes in regulatory charges ($20 million).

Purchased power expenses decreased$204 million in the nine months ended September 30, 2016 compared with the 2015 period due to lower unit costs ($169 million) and purchased volumes ($35 million).

Fuel expenses decreased$15 million in the nine months ended September 30, 2016 compared with the 2015 period due to lower unit costs ($20 million), offset by higher sendout volumes from the company’s electric generating facilities ($5 million).

Other operations and maintenance expenses decreased$18 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to a decrease in the surcharges for assessments and fees that are collected in revenues from customers ($62 million), offset in part by higher costs for municipal infrastructure support ($15 million), emergency response ($13 million), stock-based compensation ($7 million) and injuries and damages ($6 million).

Depreciation and amortizationincreased$35 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to higher electric utility plant balances.

Taxes, other than income taxesincreased$32 million in the nine months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes ($47 million), offset in part by lower state and local taxes ($6 million), a favorable state audit settlement ($4 million) and lower sales and use tax reserve based on a favorable audit settlement ($3 million).

Gas

CECONY’s results of gas operations for the nine months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$1,113	$1,177	$(64)
Gas purchased for resale	217	282	(65)
Other operations and maintenance	307	323	(16)
Depreciation and amortization	118	105	13
Taxes, other than income taxes	198	189	9
Gas operating income	$273	$278	$(5)

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CECONY’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2016 compared with the 2015 period were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016	September 30, 2015	Variation	Percent Variation
Residential	35,565	39,010	(3,445	)	(8.8	)%		$506	$532	$(26)	(4.9	)%
General	20,962	22,641	(1,679	)	(7.4	)		200	217	(17)	(7.8	)
Firm transportation	51,333	57,578	(6,245	)	(10.8	)		332	342	(10)	(2.9	)
Total firm sales and transportation	107,860	119,229	(11,369	)	(9.5	)	(b)	1,038	1,091	(53)	(4.9	)
Interruptible sales (c)	7,587	5,933	1,654		27.9			29	45	(16)	(35.6	)
NYPA	31,970	33,825	(1,855	)	(5.5	)		2	2	—	—
Generation plants	70,895	62,650	8,245		13.2			19	20	(1)	(5.0	)
Other	16,442	16,285	157		1.0			25	21	4	19.0
Other operating revenues (d)	—	—	—		—			—	(2)	2	Large
Total	234,754	237,922	(3,168	)	(1.3	)%		$1,113	$1,177	$(64)	(5.4	)%

(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.

(b) After adjusting for variations, principally billing days, firm gas sales and transportation volumes in the company’s service area increased 4.1 percent in the nine months ended September 30, 2016 compared with the 2015 period, reflecting primarily increased volumes attributable to additional customers that have converted from oil-to-gas as heating fuel for their buildings.

(c) Includes 3,940 thousands and 1,809 thousands of Dt for the 2016 and 2015 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 revenuesdecreased$64 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to lower gas purchased for resale expense ($65 million) and changes in regulatory charges ($17 million), offset in part by higher revenues from the gas rate plan ($26 million) reflecting primarily higher delivery volumes attributable to oil-to-gas conversions.

Gas purchased for resaledecreased$65 million in the nine months ended September 30, 2016 compared with the 2015 period due to lower unit costs ($48 million) and sendout volumes ($17 million).

Other operations and maintenance expenses decreased$16 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to a decrease in the surcharges for assessments and fees that are collected in revenues from customers ($19 million), offset in part by higher costs for municipal infrastructure support ($5 million).

Depreciation and amortizationincreased$13 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to higher gas utility plant balances.

Taxes, other than income taxesincreased$9 million in the nine months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes ($12 million), offset in part by lower state and local taxes ($1 million).

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Steam

CECONY’s results of steam operations for the nine months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$406	$529	$(123)
Purchased power	25	28	(3)
Fuel	52	120	(68)
Other operations and maintenance	139	140	(1)
Depreciation and amortization	62	58	4
Taxes, other than income taxes	89	83	6
Steam operating income	$39	$100	$(61)

CECONY’s steam sales and deliveries for the nine months ended September 30, 2016 compared with the 2015 period were:

	Millions of Pounds Delivered							Revenues in Millions
	For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016		September 30, 2015	Variation	Percent Variation
General	345	460	(115	)	(25.0	)%		$18		$24	$(6)	(25.0	)%
Apartment house	4,251	5,056	(805	)	(15.9	)		107		145	(38)	(26.2	)
Annual power	10,640	12,593	(1,953	)	(15.5	)		284		379	(95)	(25.1	)
Other operating revenues (a)	—	—	—		—			(3	)	(19)	16	84.2	%
Total	15,236	18,109	(2,873	)	(15.9	)%	(b)	$406		$529	$(123)	(23.3	)%

(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, principally weather and billing days, steam sales and deliveries decreased 0.5 percent in nine months ended September 30, 2016 compared with the 2015 period.

Operating revenuesdecreased$123 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to lower fuel expenses ($68 million), the weather impact on revenues ($59 million) and lower purchased power costs ($3 million), offset in part by higher revenues from the steam rate plan ($12 million).

Purchased power expenses decreased$3 million in the nine months ended September 30, 2016 compared with the 2015 period due to lower unit costs ($2 million) and purchased volumes ($1 million).

Fuel expenses decreased$68 million in the nine months ended September 30, 2016 compared with the 2015 period due to lower unit costs ($59 million) and sendout volumes from the company’s steam generating facilities ($9 million).

Other operations and maintenance expenses decreased$1 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to a decrease in the surcharges for assessments and fees that are collected in revenues from customers ($6 million), offset in part by higher costs for municipal infrastructure support ($6 million).

Depreciation and amortizationincreased$4 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to higher steam utility plant balances.

Taxes, other than income taxesincreased$6 million in the nine months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes ($9 million), offset in part by lower state and local taxes ($3 million).

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Net Interest Expense

Net interest expense increased $16 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily higher long-term debt balances in the 2016 period.

Income Tax Expense

Income taxes decreased $24 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to lower income before income tax expense ($40 million), lower state income taxes ($10 million), a research and development tax credit ($14 million) and higher settlement payments related to injuries and damages ($4 million), offset in part by plant-related flow through items ($41 million) and an increase in uncertain tax positions ($3 million).

O&R

	For the Nine Months Ended September 30, 2016			For the Nine Months Ended September 30, 2015
(Millions of Dollars)	Electric	Gas	2016 Total	Electric	Gas	2015 Total	2016-2015 Variation
Operating revenues	$497	$133	$630	$523	$117	$640	$(10)
Purchased power	154	—	154	169	—	169	(15)
Gas purchased for resale	—	32	32	—	40	40	(8)
Other operations and maintenance	180	40	220	198	51	249	(29)
Depreciation and amortization	37	13	50	38	13	51	(1)
Taxes, other than income taxes	40	20	60	33	13	46	14
Operating income	$86	$28	$114	$85	$0	$85	$29

Electric

O&R’s results of electric operations for the nine months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$497	$523	$(26)
Purchased power	154	169	(15)
Other operations and maintenance	180	198	(18)
Depreciation and amortization	37	38	(1)
Taxes, other than income taxes	40	33	7
Electric operating income	$86	$85	$1

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O&R’s electric sales and deliveries for the nine months ended September 30, 2016 compared with the 2015 period were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016	September 30, 2015	Variation	Percent Variation
Residential/Religious (b)	1,307	1,278	29		2.3	%		$240	$246	$(6)	(2.4	)%
Commercial/Industrial	607	611	(4	)	(0.7	)		89	98	(9)	(9.2	)
Retail choice customers	2,434	2,504	(70	)	(2.8	)		166	168	(2)	(1.2	)
Public authorities	76	78	(2	)	(2.6	)		6	8	(2)	(25.0	)
Other operating revenues (c)	—	—	—		—			(4)	3	(7)	Large
Total	4,424	4,471	(47	)	(1.1	)%	(d)	$497	$523	$(26)	(5.0	)%

(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 and Pennsylvania 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 plans.

(d) After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased 1.1 percent in the nine months ended September 30, 2016 compared with the 2015 period.

Operating revenuesdecreased$26 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to lower purchased power costs ($15 million) and revenues from the electric rate plans ($2 million).

Purchased power expenses decreased$15 million in the nine months ended September 30, 2016 compared with the 2015 period due to lower unit costs ($16 million), offset by lower purchased volumes ($1 million).

Other operations and maintenance expenses decreased$18 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to regulatory accounting effects of pension costs ($9 million), lower surcharges for assessments and fees that are collected in revenues from customers ($7 million) and operating costs ($3 million).

Depreciation and amortizationdecreased$1 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to lower average depreciation rates.

Taxes, other than income taxesincreased$7 million in the nine months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes.

Gas

O&R’s results of gas operations for the nine months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$133	$117	$16
Gas purchased for resale	32	40	(8)
Other operations and maintenance	40	51	(11)
Depreciation and amortization	13	13	—
Taxes, other than income taxes	20	13	7
Gas operating income	$28	$0	$28

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O&R’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2016 compared with the 2015 period were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2016	September 30, 2015	Variation		Percent Variation			September 30, 2016	September 30, 2015	Variation		Percent Variation
Residential	5,266	5,789	(523	)	(9.0	)%		$55	$55		$—	—	%
General	1,224	1,294	(70	)	(5.4	)		10	10	—		—
Firm transportation	7,188	9,012	(1,824	)	(20.2	)		49	51	(2)		(3.9	)
Total firm sales and transportation	13,678	16,095	(2,417	)	(15.0	)	(b)	114	116	(2)		(1.7	)
Interruptible sales	3,020	3,237	(217	)	(6.7	)		2	2	—		—
Generation plants	15	25	(10	)	(40.0	)		—	—	—		—
Other	583	674	(91	)	(13.5	)		—	—	—		—
Other gas revenues	—	—	—		—			17	(1)	18		Large
Total	17,296	20,031	(2,735	)	(13.7	)%		$133	$117	$16		13.7	%

(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 increased 2.3 percent in the nine months ended September 30, 2016 compared with 2015 period.

Operating revenues increased$16 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to the charge-off of certain regulatory assets in 2015 ($14 million) and higher revenues from the New York gas rate plan ($13 million), offset in part by a decrease in gas purchased for resale ($8 million).

Gas purchased for resaledecreased$8 million in the nine months ended September 30, 2016 compared with the 2015 period due to lower purchased volumes ($11 million), offset by higher unit costs ($3 million).

Other operations and maintenance expenses decreased$11 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to regulatory accounting effects of pension costs ($10 million) and lower surcharges for assessments and fees that are collected in revenues from customers ($2 million).

Taxes, other than income taxesincreased$7 million in the nine months ended September 30, 2016 compared with the 2015 period principally due to higher property taxes.

Other Income (Deductions)

Other income (deductions) increased$5 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to the impairment of certain assets held for sale in 2015 (see Note P to the Third Quarter Financial Statements).

Income Tax Expense

Income taxes increased$13 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to higher income before income tax expense ($13 million) and plant-related flow through items ($3 million), offset in part by lower state income taxes ($1 million) and lower reimbursement in insurance claims ($1 million).

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Competitive Energy Businesses

The competitive energy businesses’ results of operations for the nine months ended September 30, 2016 compared with the 2015 period is as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2016	September 30, 2015	Variation
Operating revenues	$998	$1,087	$(89)
Purchased power	676	812	(136)
Gas purchased for resale	72	94	(22)
Other operations and maintenance	124	98	26
Depreciation and amortization	30	16	14
Taxes, other than income taxes	16	14	2
Gain on sale of retail electric supply business	(104)	—	(104)
Operating income	$184	$53	$131

Operating revenuesdecreased$89 million in the nine months ended September 30, 2016 compared with the 2015 period, due primarily to lower electric retail revenues due in part to the sale of the retail electric supply business (see Note P to the Third Quarter Financial Statements). Electric retail revenues decreased $135 million due to lower unit prices ($98 million) and lower sales volume ($37 million). Wholesale revenues decreased $25 million due to lower sales volumes. Renewable revenues increased $40 million primarily due to an increase in renewable electric production projects in operation. Energy services revenues increased $31 million.

Purchased power expenses decreased$136 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to lower unit prices ($85 million), lower volumes ($46 million) and changes in mark-to-market gains ($5 million).

Gas purchased for resaledecreased$22 million in the nine months ended September 30, 2016 compared with the 2015 period due to lower sales volumes.

Other operations and maintenance expenses increased$26 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to an increase in energy services costs.

Depreciation and amortizationincreased$14 million in the nine months ended September 30, 2016 compared with the 2015 period due an increase in solar electric production projects in operation during 2016.

Gain on sale of retail electric supply business was $104 million in the nine months ended September 30, 2016 reflecting the sale of the competitive energy businesses' retail electric supply business (see Note P to the Third Quarter Financial Statements).

Other Income (Deductions)

Other income (deductions) increased$3 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to the earnings from equity investments.

Net Interest Expense

Net interest expense increased$18 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to increased debt on solar electric production projects.

Income Tax Expense

Income taxes increased$51 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to higher income before income tax expense ($46 million) and an adjustment to deferred state income taxes as a result of the sale of the retail electric supply business that increased the competitive energy businesses' state apportionment factors on its cumulative temporary differences ($13 million), offset in part by higher renewable energy tax credits ($7 million).

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Con Edison Transmission

Other Income (Deductions)

Other income (deductions) increased $23 million in the nine months ended September 30, 2016 compared with the 2015 period due primarily to earnings from the equity investments in 2016 (see Note P).

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 nine months ended September 30, 2016 and 2015 are summarized as follows:

	For the Nine Months Ended September 30,
	Con Edison			CECONY
(Millions of Dollars)	2016	2015	Variation	2016	2015	Variation
Operating activities	$2,336	$2,199	$137	$2,017	$1,802	$215
Investing activities	(3,717)	(2,687)	(1,030)	(1,943)	(1,900)	(43)
Financing activities	583	(118)	701	(891)	(496)	(395)
Net change for the period	(798)	(606)	(192)	(817)	(594)	(223)
Balance at beginning of period	944	699	245	843	645	198
Balance at end of period	146	93	53	26	51	(25)
Less: Change in cash balances held for sale	(4)	2	(6)	—	—	—
Balance at end of period excluding held for sale	$150	$91	$59	$26	$51	$(25)

Cash Flows From Operating Activities

The Utilities’ cash flows from operating activities reflect principally 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, economic conditions and measures that promote energy efficiency. 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.

Net cash flows from operating activities for the nine months ended September 30, 2016 for Con Edison and CECONY were $137 million and $215 million higher, respectively, than in the 2015 period. The change in net cash flows for Con Edison and CECONY reflects primarily the income taxes paid, net of refunds received in the 2016 period as compared with the 2015 period ($137 million and $273 million, respectively). The amount and timing of income tax payments and refunds reflect, among other things, the extension of bonus depreciation tax provisions.

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 energy costs and accounts payable balances.

Cash Flows Used in Investing Activities

Net cash flows used in investing activities for Con Edison and CECONY were $1,030 million and $43 million higher, respectively, for the nine months ended September 30, 2016 compared with the 2015 period. The change for Con Edison reflects primarily increased investments in/acquisitions of renewable electric production and electric and gas

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transmission projects ($995 million), increased utility construction expenditures in 2016 ($219 million) and increased non-utility construction expenditures related to development of renewable electric production projects ($70 million), offset in part by the proceeds from the sale of assets ($250 million). In addition, the change for CECONY reflects primarily increased utility construction expenditures in 2016 ($200 million), offset in part by the proceeds from the transfer of assets to NY Transco ($122 million).

Cash Flows From/(Used In) Financing Activities

Net cash flows from financing activities for Con Edison and CECONY were $701 million higher and $395 million lower, respectively, in the nine months ended September 30, 2016 compared with the 2015 period.

In June 2016, Con Edison borrowed $400 million pursuant to a credit agreement with a syndicate of banks. The borrowing matures in 2018 and bears interest at a LIBOR plus margin of 1.00 percent.

In 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 of 3.85 percent 30-year debentures, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes. In September 2016, CECONY redeemed at maturity $400 million of 5.50 percent 10-year debentures.

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. In June 2015, a Con Edison Development subsidiary issued $118 million aggregate principal amount of 3.94 percent senior notes, due 2036, secured by four of the company's solar projects.

In June 2015, O&R issued $120 million of 4.95 percent 30-year debentures, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes. In April 2015, O&R redeemed at maturity $40 million of 5.30 percent 10-year debentures. In August 2015, O&R redeemed at maturity $55 million of 2.50 percent 5-year debentures and $44 million of variable rate tax-exempt 20-year debt.

Cash flows used in financing activities of the Companies also reflect commercial paper issuance. The commercial paper amounts outstanding at September 30, 2016 and 2015 and the average daily balances for the nine months ended September 30, 2016 and 2015 for Con Edison and CECONY were as follows:

	2016		2015
(Millions of Dollars, except Weighted Average Yield)	Outstanding at September 30,	Daily average	Outstanding at September 30,	Daily average
Con Edison	$601	$813	$1,160	$765
CECONY	$480	$385	$649	$367
Weighted average yield	0.7%	0.6%	0.3%	0.4%

Capital Requirements and Resources

Con Edison has increased its estimates for capital requirements for 2016 from $4,892 million to $6,117 million. The increase reflects the $975 million purchase of a 50 percent equity interest in a gas pipeline and storage joint venture. See “Con Edison Transmission,” below. The increase also reflects increased estimates of capital expenditures by its competitive energy businesses from $985 million to $1,235 million to reflect additional renewable energy project development. See "Con Edison Development," below. The company plans to meet its 2016 capital requirements, including for maturing securities, through internally-generated funds and the issuance of securities. See "Cash Flows From/(Used In) Financing Activities," above. In September 2016, O&R agreed to issue

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and sell for delivery in December 2016 $75 million aggregate principal amount of 3.88 percent debentures, due 2046. CECONY plans to issue up to $750 million of long-term debt later in 2016.

Con Edison has also increased its estimates of capital expenditures by its competitive energy businesses from $360 million to $400 million for both 2017 and 2018 to reflect additional renewable energy project development.

For each of the Companies, the ratio of earnings to fixed charges (Securities and Exchange Commission basis) for the nine months ended September 30, 2016 and 2015 and the twelve months ended December 31, 2015 was:

	Ratio of Earnings to Fixed Charges
	For the Nine Months Ended September 30, 2016	For the Nine Months Ended September 30, 2015	For the Twelve Months Ended December 31, 2015
Con Edison	4.0	3.9	3.5
CECONY	3.8	4.1	3.6

For each of the Companies, the common equity ratio at September 30, 2016 and December 31, 2015 was:

	Common Equity Ratio (Percent of total capitalization)
	September 30, 2016	December 31, 2015
Con Edison	50.9	52.1
CECONY	51.0	51.4

Contractual Obligations

Con Edison’s obligations to make payments pursuant to contracts increased to $38,611 million at September 30, 2016 from $34,884 million at December 31, 2015 due primarily to increases in the company’s long-term debt ($1,358 million, including $150 million for CECONY, see "Cash Flows From/(Used In) Financing Activities," above) and interest on long-term debt ($891 million, including $704 million for CECONY). The change also reflects increases in obligations under natural gas supply, transportation and storage contracts ($1,862 million, including $1,577 million for CECONY). In addition, in October 2016, CECONY's obligations increased by $878 million reflecting the estimated aggregate annual amounts payable under the twenty-year renewal of the New York City revocable consent for the use of streets and public places for installation and operation of transformers and associated vaults and equipment. 

Other Changes in Assets and Liabilities

The following table shows changes in certain assets and liabilities at September 30, 2016, compared with December 31, 2015.

	Con Edison	CECONY
(Millions of Dollars)	2016 vs. 2015 Variation	2016 vs. 2015 Variation
Assets
Investments	$1,047	$32
Prepayments	403	351
Regulatory asset — Unrecognized pension and other postretirement costs	(507)	(477)
Income taxes receivable	(100)	—
Liabilities
Deferred income taxes and investment tax credits	$618	$717
Pension and retiree benefits	(714)	(670)

Investments

The increase in investments for Con Edison reflects the purchase of a 50 percent equity interest in a natural gas pipeline and storage joint venture. See “Con Edison Transmission,” below and Note P to the Third Quarter Financial Statements.

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Prepayments

The increase in prepayments for Con Edison and CECONY reflects primarily the portion allocable to the 2016 fourth quarter of CECONY's July 2016 payment of its New York City semi-annual property taxes.

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, 2015, 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 2016. See Notes B, E and F to the Third Quarter Financial Statements.

Income Taxes Receivable

The decrease in income taxes receivable for Con Edison reflects primarily the refund received in February 2016 from the Internal Revenue Service as a result of the extension of bonus depreciation in December 2015.

Deferred Income Taxes and Investment Tax Credits

The increase in the liability for deferred income taxes and investment tax credits for Con Edison and CECONY reflects primarily bonus depreciation in 2016, 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.

Off-Balance Sheet Arrangements

None of the Companies’ interests in variable interest entities (VIEs) meet the Securities and Exchange Commission definition of off-balance sheet arrangements. For information regarding the Companies’ VIEs, see Note M to the Third Quarter Financial Statements.

Regulatory Matters

In March 2016, the New York State Public Service Commission (NYSPSC) issued an order in which it approved CECONY’s advanced metering infrastructure (AMI) plan for the company’s electric and gas delivery businesses, subject to a cap on capital expenditures of $1,285 million. AMI components include smart meters, a communication network, information technology systems and business applications. The plan provides for full deployment of AMI to the company’s customers to be implemented over a six-year period. The NYSPSC directed CECONY to submit a customer engagement plan, an update to the company’s benefit cost analysis and metrics that the NYSPSC can use to monitor the success of the project.

In May 2016, the NYSPSC issued an order in its Reforming the Energy Vision (REV) proceeding adopting a ratemaking and utility revenue framework. The order indicated that utilities will have four ways of achieving earnings: traditional cost-of-service earnings; earnings tied to achievement of alternatives that reduce utility capital spending and provide definitive consumer benefit; earnings from market-facing platform activities; and transitional outcome-based performance measures. The order also indicated, among other things, that existing measures for negative revenue adjustments for utility failure to meet basic service standards should generally be retained and net utility plant reconciliations should be modified to encourage cost-effective distributed energy resources (DER) as an alternative to utility capital investment. The order directs each utility to file a system efficiency proposal; an interconnection survey process and proposed earnings adjustment mechanism; a progress report on aggregated data reporting automation; an aggregated data privacy policy statement; revisions to standby service tariffs and cost allocation matrix; one or more smart home rate demonstration proposals; and revisions to voluntary time of use rates and promotion and education tools.

In June 2016, CECONY and O&R each filed initial distributed system implementation plans with the NYSPSC, pursuant to which the companies provide additional system and planning information for third-party developers to facilitate the integration of DER in the distributed system platform.

In August 2016, the NYSPSC issued an order adopting the New York State Energy Plan’s goal of 50 percent of the State’s electricity to be generated by renewable sources by 2030 as part of a strategy to reduce statewide greenhouse gas emissions 40 percent by 2030. The NYSPSC also adopted a Clean Energy Standard (CES) that

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includes renewable energy credit (REC) and zero-emissions credit (ZEC) requirements. Beginning in 2017, load serving entities (LSEs), including CECONY and O&R for their full-service customers, will be required to obtain RECs and ZECs in amounts determined by the NYSPSC. LSEs may satisfy their REC obligation by either purchasing RECs acquired through central procurement by the New York State Energy Research and Development Authority (NYSERDA), by self-supply through direct purchase of tradable RECs, or by making alternative compliance payments. LSEs will purchase ZECs from NYSERDA at prices determined by the NYSPSC. The order establishes an annual NYSPSC staff review and triennial NYSPSC review of the CES. 

For certain information about the Utilities' rate plans and other regulatory matters affecting the Companies, see Note B to the Third Quarter Financial Statements.

Con Edison Development

The following table provides information about the renewable electric production projects Con Edison Development owned at September 30, 2016:

Project Name	Production Technology	Generating Capacity (a) (MW AC)	Power Purchase Agreement Term (in Years)	Actual/Expected In-Service Date	Location
Wholly owned projects
Pilesgrove (c)	Solar	18	n/a (b)	2011	New Jersey
Flemington Solar	Solar	8	n/a (b)	2011	New Jersey
Frenchtown I, II and III	Solar	14	n/a (b)	2011-13	New Jersey
PA Solar	Solar	10	n/a (b)	2012	Pennsylvania
California Solar 2	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	Solar	95	25	2015	Texas
Campbell County Wind	Wind	95	30	2015	South Dakota
Texas Solar 7 (c)	Solar	106	25	2016	Texas
Projects of less than 5 MW	Solar	20	Various (b)	Various	Various
Jointly owned projects (d)
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		883
California Solar 3	Solar	110	20	2016	California
Upton County	Solar	150	25	2017	Texas
Panoche Valley (d)	Solar	120	20	2019	California
Total MW (AC) in Construction		380
Total MW (AC), All Projects		1,263 (e)

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

(b) New Jersey, Pennsylvania and Massachusetts assets have 3-4 year Solar Renewable Energy Credit hedges in place.

(c) See Note P to the Third Quarter Financial Statements.

(d) See Note M to the Third Quarter Financial Statements.

(e) Additionally, in October 2015, Con Edison Development purchased Lost Hills, which is developing but has not started constructing, a 20 MW (AC) solar electric production project in California.

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Con Edison Transmission

CET Electric

In March 2016, the Federal Energy Regulatory Commission approved a November 2015 settlement agreement applicable to three transmission projects that the NYSPSC approved in October 2013 in its proceeding to address potential needs that could arise should the Indian Point Energy Center (which is owned by Entergy Corporation subsidiaries) no longer be able to operate. CECONY developed and, in May 2016, transferred two of the projects to New York Transco LLC. See Note P to the Third Quarter Financial Statements. The settlement agreement, among other things, provides for a 10 percent return on common equity (and/or 9.5 percent for capital costs in excess of $228 million incurred for initial commercial operation), a maximum common equity ratio of 53 percent and allocation of 63 percent of the costs of the projects to load serving entities in the CECONY and O&R service areas.

CET Gas

In April 2016, a CET Gas subsidiary agreed with a subsidiary of Crestwood Equity Partners LP to form a joint venture to own, operate and further develop a gas pipeline and storage business located in northern Pennsylvania and southern New York. In June 2016, the transaction was substantially completed. See Note P to the Third Quarter Financial Statements.

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 September 30, 2016, a 10 percent increase in interest rates applicable to its variable rate debt would result in an increase in annual interest expense of $2 million. Under CECONY’s current gas, steam and electric 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 Con Edison’s competitive energy businesses apply risk management strategies to mitigate their related exposures. See Note K to the Third Quarter Financial Statements.

Con Edison estimates that, as of September 30, 2016, a 10 percent decline in market prices would result in a decline in fair value of $61 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $54 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.

Con Edison’s competitive 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 nine months ended September 30, 2016 and the year ended December 31, 2015, respectively, was as follows:

72

95% Confidence Level, One-Day Holding Period	September 30, 2016	December 31, 2015
	(Millions of Dollars)
Average for the period	$2	$1
High	4	2
Low	1	—

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 competitive energy businesses. See Note K to the Third Quarter Financial Statements.

Investment Risk

The Companies’ investment risk relates to the investment of plan assets for their pension and other postretirement benefit plans. The Companies’ current investment policy for pension plan assets includes investment targets of 55 to 65 percent equities and 35 to 45 percent fixed income and other securities. At September 30, 2016, 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 Notes B, G and H to the Third Quarter Financial Statements.

73

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.

74

Part II Other Information

Item 1: Legal Proceedings

For information about certain legal proceedings affecting the Companies, see Notes B, G and H to the financial statements in Part I, Item 1 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 12.1	Statement of computation of Con Edison’s ratio of earnings to fixed charges for the nine-month periods ended September 30, 2016 and 2015, and the 12-month period ended December 31, 2015.
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 12.2	Statement of computation of CECONY’s ratio of earnings to fixed charges for the nine-month periods ended September 30, 2016 and 2015, and the 12-month period ended December 31, 2015.
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.

75

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: November 3, 2016	By	/s/ Robert Hoglund
		Robert Hoglund Senior Vice President, Chief Financial Officer and Duly Authorized Officer

76

EX-12.1

Exhibit 12.1

Consolidated Edison, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Nine Months Ended September 30, 2016	For The Twelve Months Ended December 31, 2015	For the Nine Months Ended September 30, 2015
Earnings
Net Income	$1,039	$1,193	$1,017
Preferred Stock Dividend	—	—	—
(Income)/Loss from Equity Investees	(28)	(34)	(33)
Minority Interest Loss	—	—	—
Income Tax	602	605	548
Pre-Tax Income	$1,613	$1,764	$1,532
Add: Fixed Charges*	542	701	522
Add: Distributed Income of Equity Investees	—	—	—
Subtract: Interest Capitalized	—	—	—
Subtract: Pre-Tax Preferred Stock Dividend Requirement	—	—	—
Earnings	$2,155	$2,465	$2,054
* Fixed Charges
Interest on Long-term Debt	$493	$618	$458
Amortization of Debt Discount, Premium and Expense	11	14	11
Interest Capitalized	—	—	—
Other Interest	17	24	19
Interest Component of Rentals	21	45	34
Pre-Tax Preferred Stock Dividend Requirement	—	—	—
Fixed Charges	$542	$701	$522
Ratio of Earnings to Fixed Charges	4.0	3.5	3.9

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 September 30, 2016 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: November 3, 2016

/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 September 30, 2016 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: November 3, 2016

/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 September 30, 2016, 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: November 3, 2016

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 September 30, 2016, 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: November 3, 2016

EX-12.2

Exhibit 12.2

Consolidated Edison Company of New York, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Nine Months Ended September 30, 2016	For the Twelve Months Ended December 31, 2015	For the Nine Months Ended September 30, 2015
Earnings
Net Income	$859	$1,084	$935
Preferred Stock Dividend	—	—	—
(Income)/Loss from Equity Investees	—	—	—
Minority Interest Loss	—	—	—
Income Tax	491	574	515
Pre-Tax Income	$1,350	$1,658	$1,450
Add: Fixed Charges*	474	629	469
Add: Distributed Income of Equity Investees	—	—	—
Subtract: Interest Capitalized	—	—	—
Subtract: Pre-Tax Preferred Stock Dividend Requirement	—	—	—
Earnings	$1,824	$2,287	$1,919
* Fixed Charges
Interest on Long-term Debt	$430	$553	$413
Amortization of Debt Discount, Premium and Expense	10	14	10
Interest Capitalized	—	—	—
Other Interest	14	19	14
Interest Component of Rentals	20	43	32
Pre-Tax Preferred Stock Dividend Requirement	—	—	—
Fixed Charges	$474	$629	$469
Ratio of Earnings to Fixed Charges	3.8	3.6	4.1

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 September 30, 2016 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: November 3, 2016

/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 September 30, 2016 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: November 3, 2016

/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 September 30, 2016, 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: November 3, 2016

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 September 30, 2016, 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: November 3, 2016

XML

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Oct. 28, 2016
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q3
Trading Symbol	ED
Entity Registrant Name	CONSOLIDATED EDISON INC
Entity Central Index Key	0001047862
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		304,727,523
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		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
OPERATING REVENUES
Electric	$ 2,769	$ 2,762	$ 6,717	$ 6,937
Gas	235	237	1,246	1,293
Steam	63	58	406	529
Non-utility	350	386	999	1,088
TOTAL OPERATING REVENUES	3,417	3,443	9,368	9,847
OPERATING EXPENSES
Purchased power	798	860	2,047	2,404
Fuel	29	31	133	216
Gas purchased for resale	81	64	320	415
Other operations and maintenance	840	869	2,447	2,485
Depreciation and amortization	305	285	905	840
Taxes, other than income taxes	528	504	1,523	1,459
TOTAL OPERATING EXPENSES	2,581	2,613	7,375	7,819
Gain on sale of retail electric supply business	104	0	104	0
OPERATING INCOME	940	830	2,097	2,028
OTHER INCOME (DEDUCTIONS)
Investment and other income	51	12	70	31
Allowance for equity funds used during construction	3	1	7	3
Other deductions	(5)	(4)	(16)	(11)
TOTAL OTHER INCOME (DEDUCTIONS)	49	9	61	23
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	989	839	2,158	2,051
INTEREST EXPENSE
Interest on long-term debt	174	157	504	469
Other interest	5	6	17	19
Allowance for borrowed funds used during construction	(1)	(1)	(4)	(2)
NET INTEREST EXPENSE	178	162	517	486
INCOME BEFORE INCOME TAX EXPENSE	811	677	1,641	1,565
INCOME TAX EXPENSE	314	249	602	548
NET INCOME	$ 497	$ 428	$ 1,039	$ 1,017
Net income per common share-basic (dollars per share)	$ 1.63	$ 1.46	$ 3.47	$ 3.47
Net income per common share-diluted (dollars per share)	1.62	1.45	3.46	3.46
DIVIDENDS DECLARED PER COMMON SHARE (dollars per share)	$ 0.67	$ 0.65	$ 2.01	$ 1.95
AVERAGE NUMBER OF SHARES OUTSTANDING-BASIC (IN MILLIONS) (shares)	304.5	292.9	299.1	292.9
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS) (shares)	305.9	294.2	300.5	294.2
CECONY
OPERATING REVENUES
Electric	$ 2,557	$ 2,558	$ 6,222	$ 6,416
Gas	208	213	1,113	1,177
Steam	63	58	406	529
TOTAL OPERATING REVENUES	2,828	2,829	7,741	8,122
OPERATING EXPENSES
Purchased power	495	526	1,216	1,423
Fuel	29	31	133	216
Gas purchased for resale	34	30	217	282
Other operations and maintenance	724	750	2,105	2,140
Depreciation and amortization	278	262	825	773
Taxes, other than income taxes	502	485	1,446	1,399
TOTAL OPERATING EXPENSES	2,062	2,084	5,942	6,233
OPERATING INCOME	766	745	1,799	1,889
OTHER INCOME (DEDUCTIONS)
Investment and other income	4	(1)	6	3
Allowance for equity funds used during construction	2	1	6	3
Other deductions	(4)	(3)	(10)	(10)
TOTAL OTHER INCOME (DEDUCTIONS)	2	(3)	2	(4)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	768	742	1,801	1,885
INTEREST EXPENSE
Interest on long-term debt	150	141	440	423
Other interest	5	5	14	14
Allowance for borrowed funds used during construction	(1)	(1)	(3)	(2)
NET INTEREST EXPENSE	154	145	451	435
INCOME BEFORE INCOME TAX EXPENSE	614	597	1,350	1,450
INCOME TAX EXPENSE	226	222	491	515
NET INCOME	$ 388	$ 375	$ 859	$ 935

XML

Consolidated Statement of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
NET INCOME	$ 497	$ 428	$ 1,039	$ 1,017
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	1	2	7
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	2	7
COMPREHENSIVE INCOME	498	429	1,041	1,024
CECONY
NET INCOME	388	375	859	935
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	0	1	1	2
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	0	1	1	2
COMPREHENSIVE INCOME	$ 388	$ 376	$ 860	$ 937

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Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
OPERATING ACTIVITIES
NET INCOME	$ 1,039	$ 1,017
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	905	840
Deferred income taxes	524	466
Rate case amortization and accruals	(157)	(38)
Common equity component of allowance for funds used during construction	(7)	(3)
Net derivative (gains)/losses	(7)	(4)
Pre-tax gain on sale of retail electric supply business	(104)	0
Other non-cash items, net	99	73
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(138)	(82)
Materials and supplies, including fuel oil and gas in storage	15	32
Other receivables and other current assets	90	44
Income taxes receivable	100	194
Prepayments	(403)	(568)
Accounts payable	142	83
Pensions and retiree benefits obligations, net	464	566
Pensions and retiree benefits contributions	(510)	(753)
Accrued taxes	(21)	(19)
Accrued interest	66	48
Superfund and environmental remediation costs, net	68	23
Distributions from equity investments	45	29
Deferred charges, noncurrent assets and other regulatory assets	(104)	(17)
Deferred credits and other regulatory liabilities	116	220
Other current and noncurrent liabilities	114	48
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,336	2,199
INVESTING ACTIVITIES
Utility construction expenditures	(2,057)	(1,838)
Cost of removal less salvage	(149)	(156)
Non-utility construction expenditures	(436)	(366)
Investments in/acquisitions of renewable electric production and electric and gas transmission projects	(1,281)	(286)
Proceeds from sale of assets	250	0
Proceeds from the transfer of assets to NY Transco	122	0
Restricted cash	(21)	(23)
Other investing activities	(145)	(18)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,717)	(2,687)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(928)	360
Issuance of long-term debt	1,765	238
Retirement of long-term debt	(407)	(145)
Debt issuance costs	(16)	(2)
Common stock dividends	(570)	(560)
Issuance of common shares - public offering	702	0
Issuance of common shares for stock plans, net of repurchases	38	(9)
Distribution to noncontrolling interest	(1)	0
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	583	(118)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(798)	(606)
BALANCE AT BEGINNING OF PERIOD	944	699
BALANCE AT END OF PERIOD	146	93
LESS: CHANGE IN CASH BALANCES HELD FOR SALE	(4)	2
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	150	91
Cash paid/(received) during the period for:
Interest	437	411
Income taxes	(144)	(7)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	242	204
Issuance of common shares for dividend reinvestment	35	11
CECONY
OPERATING ACTIVITIES
NET INCOME	859	935
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	825	773
Deferred income taxes	569	391
Rate case amortization and accruals	(170)	(57)
Common equity component of allowance for funds used during construction	(6)	(3)
Other non-cash items, net	7	13
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(79)	(51)
Materials and supplies, including fuel oil and gas in storage	15	34
Other receivables and other current assets	18	60
Accounts receivable from affiliated companies	38	(32)
Prepayments	(351)	(336)
Accounts payable	82	18
Accounts payable to affiliated companies	8	5
Pensions and retiree benefits obligations, net	439	530
Pensions and retiree benefits contributions	(472)	(700)
Accrued taxes	(17)	(1)
Accrued interest	43	37
Superfund and environmental remediation costs, net	76	21
Accrued taxes to affiliated companies	(2)	(8)
Deferred charges, noncurrent assets and other regulatory assets	(153)	(49)
Deferred credits and other regulatory liabilities	165	222
Other current and noncurrent liabilities	123	0
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,017	1,802
INVESTING ACTIVITIES
Utility construction expenditures	(1,932)	(1,732)
Cost of removal less salvage	(146)	(149)
Proceeds from the transfer of assets to NY Transco	122	0
Restricted cash	13	(19)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,943)	(1,900)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(553)	199
Issuance of long-term debt	550	0
Retirement of long-term debt	(400)	0
Debt issuance costs	(6)	(1)
Capital contribution by parent	76	0
Dividend to parent	(558)	(694)
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	(891)	(496)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(817)	(594)
BALANCE AT BEGINNING OF PERIOD	843	645
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	26	51
Cash paid/(received) during the period for:
Interest	386	376
Income taxes	(130)	143
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$ 195	$ 152

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Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
CURRENT ASSETS
Cash and temporary cash investments	$ 150	$ 944
Special deposits	3	3
Accounts receivable - customers, less allowance for uncollectible accounts	1,157	1,052
Other receivables, less allowance for uncollectible accounts	165	304
Income taxes receivable	66	166
Accrued unbilled revenue	373	360
Fuel oil, gas in storage, materials and supplies, at average cost	335	350
Prepayments	580	177
Regulatory assets	119	132
Assets held for sale	0	157
Other current assets	206	191
TOTAL CURRENT ASSETS	3,154	3,836
INVESTMENTS	1,931	884
UTILITY PLANT, AT ORIGINAL COST
General	2,657	2,622
TOTAL	39,523	38,174
Less: Accumulated depreciation	8,451	8,044
Net	31,072	30,130
Construction work in progress	1,286	1,003
NET UTILITY PLANT	32,358	31,133
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	1,127	832
Construction work in progress	421	244
NET PLANT	33,906	32,209
OTHER NONCURRENT ASSETS
Goodwill	429	429
Intangible assets, less accumulated amortization of $5 and $4 in 2016 and 2015, respectively	0	2
Regulatory assets	7,544	8,096
Other deferred charges and noncurrent assets	352	186
TOTAL OTHER NONCURRENT ASSETS	8,325	8,713
TOTAL ASSETS	47,316	45,642
CURRENT LIABILITIES
Long-term debt due within one year	346	739
Notes payable	601	1,529
Accounts payable	1,113	1,008
Customer deposits	356	354
Accrued taxes	41	62
Accrued interest	202	136
Accrued wages	101	97
Fair value of derivative liabilities	70	66
Regulatory liabilities	123	115
Liabilities held for sale	0	89
Other current liabilities	638	525
TOTAL CURRENT LIABILITIES	3,591	4,720
NONCURRENT LIABILITIES
Provision for injuries and damages	170	185
Pensions and retiree benefits	2,197	2,911
Superfund and other environmental costs	752	765
Asset retirement obligations	254	242
Fair value of derivative liabilities	52	39
Deferred income taxes and unamortized investment tax credits	10,155	9,537
Regulatory liabilities	1,920	1,977
Other deferred credits and noncurrent liabilities	203	199
TOTAL NONCURRENT LIABILITIES	15,703	15,855
LONG-TERM DEBT	13,747	12,006
EQUITY
Common shareholders’ equity	14,267	13,052
Noncontrolling interest	8	9
TOTAL EQUITY (See Statement of Equity)	14,275	13,061
TOTAL LIABILITIES AND EQUITY	47,316	45,642
CECONY
CURRENT ASSETS
Cash and temporary cash investments	26	843
Special deposits	2	2
Accounts receivable - customers, less allowance for uncollectible accounts	1,076	987
Other receivables, less allowance for uncollectible accounts	55	70
Accrued unbilled revenue	330	327
Accounts receivable from affiliated companies	152	190
Fuel oil, gas in storage, materials and supplies, at average cost	273	288
Prepayments	464	113
Regulatory assets	111	121
Other current assets	98	131
TOTAL CURRENT ASSETS	2,587	3,072
INVESTMENTS	318	286
UTILITY PLANT, AT ORIGINAL COST
General	2,437	2,411
TOTAL	37,023	35,766
Less: Accumulated depreciation	7,750	7,378
Net	29,273	28,388
Construction work in progress	1,200	922
NET UTILITY PLANT	30,473	29,310
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	4	5
NET PLANT	30,477	29,315
OTHER NONCURRENT ASSETS
Regulatory assets	6,986	7,482
Other deferred charges and noncurrent assets	68	75
TOTAL OTHER NONCURRENT ASSETS	7,054	7,557
TOTAL ASSETS	40,436	40,230
CURRENT LIABILITIES
Long-term debt due within one year	250	650
Notes payable	480	1,033
Accounts payable	838	771
Accounts payable to affiliated companies	20	12
Customer deposits	341	339
Accrued taxes	32	49
Accrued taxes to affiliated companies	0	2
Accrued interest	161	118
Accrued wages	92	88
Fair value of derivative liabilities	61	50
Regulatory liabilities	96	84
Other current liabilities	558	443
TOTAL CURRENT LIABILITIES	2,929	3,639
NONCURRENT LIABILITIES
Provision for injuries and damages	164	178
Pensions and retiree benefits	1,895	2,565
Superfund and other environmental costs	661	665
Asset retirement obligations	241	234
Fair value of derivative liabilities	45	36
Deferred income taxes and unamortized investment tax credits	9,472	8,755
Regulatory liabilities	1,725	1,789
Other deferred credits and noncurrent liabilities	177	167
TOTAL NONCURRENT LIABILITIES	14,380	14,389
LONG-TERM DEBT	11,334	10,787
EQUITY
Common shareholders’ equity	11,793	11,415
TOTAL LIABILITIES AND EQUITY	40,436	40,230
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	27,239	26,358
Electric | CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	25,648	24,828
OTHER NONCURRENT ASSETS
TOTAL ASSETS	30,580
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	7,253	6,858
Gas | CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	6,564	6,191
OTHER NONCURRENT ASSETS
TOTAL ASSETS	7,300
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,374	2,336
Steam | CECONY
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,374	$ 2,336
OTHER NONCURRENT ASSETS
TOTAL ASSETS	$ 2,556

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Consolidated Balance Sheet (Unaudited) (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Accounts receivable - customers, allowance for uncollectible accounts	$ 75	$ 85
Other receivables, allowance for uncollectible accounts	13	11
Non-utility property, accumulated depreciation	122	95
Intangible assets, accumulated amortization	5	4
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	70	80
Other receivables, allowance for uncollectible accounts	12	11
Non-utility property, accumulated depreciation	$ 25	$ 25

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Consolidated Statement of Equity/Shareholder's Equity (Unaudited) - USD ($) $ in Millions	Total	CECONY	Common Stock	Common Stock CECONY	Additional Paid-In Capital	Additional Paid-In Capital CECONY	Retained Earnings	Retained Earnings CECONY	Repurchased Con Edison Stock CECONY	Treasury Stock	Capital Stock Expense	Capital Stock Expense CECONY	Accumulated Other Comprehensive Income/(Loss)	Accumulated Other Comprehensive Income/(Loss) CECONY	Noncontrolling Interest
Beginning Balance at Dec. 31, 2014	$ 12,585		$ 32		$ 4,991		$ 8,691			$ (1,032)	$ (61)		$ (45)	$ (11)	$ 9
Beginning Balance at Dec. 31, 2014		$ 11,188		$ 589		$ 4,234		$ 7,399	$ (962)			$ (61)		(11)
Beginning Balance (in shares) at Dec. 31, 2014			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	370	348					370	348
Common stock dividends	(190)	(338)					(190)	(338)
Issuance of common shares for stock plans, net of repurchases					2					$ (2)
Other comprehensive income	5	0											5	0
Ending Balance at Mar. 31, 2015		11,198		$ 589		4,234		7,409	(962)			(61)		(11)
Ending Balance at Mar. 31, 2015	12,770		$ 32		4,993		8,871			$ (1,034)	(61)		(40)		9
Ending Balance (in shares) at Mar. 31, 2015			293,000,000	235,000,000						23,000,000
Beginning Balance at Dec. 31, 2014	12,585		$ 32		4,991		8,691			$ (1,032)	(61)		(45)	(11)	9
Beginning Balance at Dec. 31, 2014		11,188		$ 589		4,234		7,399	(962)			(61)		(11)
Beginning Balance (in shares) at Dec. 31, 2014			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,017	935
Ending Balance at Sep. 30, 2015		11,430		$ 589		4,234		7,639	(962)			(61)		(9)
Ending Balance at Sep. 30, 2015	13,049		$ 32		5,008		9,137			$ (1,038)	(61)		(38)	(9)	9
Ending Balance (in shares) at Sep. 30, 2015			293,000,000	235,000,000						23,000,000
Beginning Balance at Mar. 31, 2015	12,770		$ 32		4,993		8,871			$ (1,034)	(61)		(40)		9
Beginning Balance at Mar. 31, 2015		11,198		$ 589		4,234		7,409	(962)			(61)		(11)
Beginning Balance (in shares) at Mar. 31, 2015			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	219	211					219	211
Common stock dividends	(190)	(178)					(190)	(178)
Issuance of common shares for stock plans, net of repurchases	(3)									$ (3)
Other comprehensive income	1	1											1	1
Ending Balance at Jun. 30, 2015		11,232		$ 589		4,234		7,442	(962)			(61)		(10)
Ending Balance at Jun. 30, 2015	12,797		$ 32		4,993		8,900			$ (1,037)	(61)		(39)	(10)	9
Ending Balance (in shares) at Jun. 30, 2015			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	428	375					428	375
Common stock dividends	(191)	(178)					(191)	(178)
Issuance of common shares for stock plans, net of repurchases	14				15					$ (1)
Other comprehensive income	1	1											1	1
Ending Balance at Sep. 30, 2015		11,430		$ 589		4,234		7,639	(962)			(61)		(9)
Ending Balance at Sep. 30, 2015	13,049		$ 32		5,008		9,137			$ (1,038)	(61)		(38)	(9)	9
Ending Balance (in shares) at Sep. 30, 2015			293,000,000	235,000,000						23,000,000
Beginning Balance at Dec. 31, 2015	13,061		$ 32		5,030		9,123			$ (1,038)	(61)		(34)	(9)	9
Beginning Balance at Dec. 31, 2015	13,052	11,415		$ 589		4,247		7,611	(962)			(61)		(9)
Beginning Balance (in shares) at Dec. 31, 2015			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	310	310					310	310
Common stock dividends	(197)	(186)					(197)	(186)
Issuance of common shares for stock plans, net of repurchases	28				28
Issuance of common shares for stock plans, net of repurchases (in shares)			1,000,000
Capital contribution by parent		23				23
Other comprehensive income	0	0											0	0
Noncontrolling interest	(1)														(1)
Ending Balance at Mar. 31, 2016		11,562		$ 589		4,270		7,735	(962)			(61)		(9)
Ending Balance at Mar. 31, 2016	13,201		$ 32		5,058		9,236			$ (1,038)	(61)		(34)		8
Ending Balance (in shares) at Mar. 31, 2016			294,000,000	235,000,000						23,000,000
Beginning Balance at Dec. 31, 2015	13,061		$ 32		5,030		9,123			$ (1,038)	(61)		(34)	(9)	9
Beginning Balance at Dec. 31, 2015	13,052	11,415		$ 589		4,247		7,611	(962)			(61)		(9)
Beginning Balance (in shares) at Dec. 31, 2015			293,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,039	859
Ending Balance at Sep. 30, 2016	14,267	11,793		$ 589		4,323		7,912	(962)			(61)		(8)
Ending Balance at Sep. 30, 2016	14,275		$ 33		5,830		9,557			$ (1,038)	(83)		(32)	(8)	8
Ending Balance (in shares) at Sep. 30, 2016			305,000,000	235,000,000						23,000,000
Beginning Balance at Mar. 31, 2016	13,201		$ 32		5,058		9,236			$ (1,038)	(61)		(34)		8
Beginning Balance at Mar. 31, 2016		11,562		$ 589		4,270		7,735	(962)			(61)		(9)
Beginning Balance (in shares) at Mar. 31, 2016			294,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	232	161					232	161
Common stock dividends	(204)	(186)					(204)	(186)
Issuance of common shares - public offering	702		$ 1		723						(22)
Issuance of common shares - public offering (in shares)			10,000,000
Issuance of common shares for stock plans, net of repurchases	26				26
Capital contribution by parent		28				28
Other comprehensive income	1	1											1	1
Ending Balance at Jun. 30, 2016		11,566		$ 589		4,298		7,710	(962)			(61)		(8)
Ending Balance at Jun. 30, 2016	13,958		$ 33		5,807		9,264			$ (1,038)	(83)		(33)	(8)	8
Ending Balance (in shares) at Jun. 30, 2016			304,000,000	235,000,000						23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	497	388					497	388
Common stock dividends	(204)	(186)					(204)	(186)
Issuance of common shares for stock plans, net of repurchases	23				23
Issuance of common shares for stock plans, net of repurchases (in shares)			1,000,000
Capital contribution by parent		25				25
Other comprehensive income	1	0											1	0
Ending Balance at Sep. 30, 2016	14,267	$ 11,793		$ 589		$ 4,323		$ 7,912	$ (962)			$ (61)		(8)
Ending Balance at Sep. 30, 2016	$ 14,275		$ 33		$ 5,830		$ 9,557			$ (1,038)	$ (83)		$ (32)	$ (8)	$ 8
Ending Balance (in shares) at Sep. 30, 2016			305,000,000	235,000,000						23,000,000

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General

9 Months Ended

Sep. 30, 2016

General

General

These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Con Edison’s other utility subsidiary, Orange and Rockland Utilities, Inc. (O&R), Con Edison Transmission, Inc. (Con Edison Transmission) and Con Edison’s competitive energy businesses in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R.

As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself.

The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies’ separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2015 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Report on Form 10-Q for the quarterly periods ended March 31, 2016 and June 30, 2016. Certain prior period amounts have been reclassified to conform to the current period presentation.

Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiary, provides electric service in southeastern New York and northern New Jersey and gas service in southeastern New York. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company which provides energy-related products and services to retail customers; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects. In addition, Con Edison has a subsidiary, Con Edison Transmission, that invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See Note P.

CECONY

General

General

These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Con Edison’s other utility subsidiary, Orange and Rockland Utilities, Inc. (O&R), Con Edison Transmission, Inc. (Con Edison Transmission) and Con Edison’s competitive energy businesses in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R.

As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself.

The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies’ separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2015 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Report on Form 10-Q for the quarterly periods ended March 31, 2016 and June 30, 2016. Certain prior period amounts have been reclassified to conform to the current period presentation.

Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiary, provides electric service in southeastern New York and northern New Jersey and gas service in southeastern New York. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company which provides energy-related products and services to retail customers; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects. In addition, Con Edison has a subsidiary, Con Edison Transmission, that invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See Note P.

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Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2016

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Earnings Per Common Share

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

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2016	2015
Net income	$497	$428	$1,039	$1,017
Weighted average common shares outstanding – basic	304.5	292.9	299.1	292.9
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	305.9	294.2	300.5	294.2
Net income per common share – basic	$1.63	$1.46	$3.47	$3.47
Net income per common share – diluted	$1.62	$1.45	$3.46	$3.46

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

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(33)	$(39)	$(8)	$(10)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015 (a)(b)	1	1	—	1
Current period OCI, net of taxes	1	1	—	1
Ending balance, accumulated OCI, net of taxes	$(32)	$(38)	$(8)	$(9)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(45)	$(9)	$(11)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively	(1)	3	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) and $(3) for Con Edison in 2016 and 2015 (a)(b)	3	4	1	2
Current period OCI, net of taxes	2	7	1	2
Ending balance, accumulated OCI, net of taxes	$(32)	$(38)	$(8)	$(9)

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

(b) For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of total periodic pension and other postretirement benefit cost. See Notes E and F.

CECONY

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Earnings Per Common Share

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

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2016	2015
Net income	$497	$428	$1,039	$1,017
Weighted average common shares outstanding – basic	304.5	292.9	299.1	292.9
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	305.9	294.2	300.5	294.2
Net income per common share – basic	$1.63	$1.46	$3.47	$3.47
Net income per common share – diluted	$1.62	$1.45	$3.46	$3.46

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

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(33)	$(39)	$(8)	$(10)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015 (a)(b)	1	1	—	1
Current period OCI, net of taxes	1	1	—	1
Ending balance, accumulated OCI, net of taxes	$(32)	$(38)	$(8)	$(9)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(45)	$(9)	$(11)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively	(1)	3	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) and $(3) for Con Edison in 2016 and 2015 (a)(b)	3	4	1	2
Current period OCI, net of taxes	2	7	1	2
Ending balance, accumulated OCI, net of taxes	$(32)	$(38)	$(8)	$(9)

(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

9 Months Ended

Sep. 30, 2016

Public Utilities, General Disclosures [Line Items]

Regulatory Matters

Regulatory Matters

Rate Plans

CECONY - Electric

In September 2016, CECONY, the staff of the New York State Public Service Commission (NYSPSC) and other parties entered into a Joint Proposal for a CECONY electric rate plan for the three-year period January 2017 through December 2019. The Joint Proposal is subject to NYSPSC approval. The following table contains a summary of the electric rate plan.

Effective period	January 2017 - December 2019
Base rate changes (a)	Yr. 1 - $195 million Yr. 2 - $155 million Yr. 3 - $155 million
Amortizations to income of net regulatory (assets) liabilities	Yr. 1 - $84 million Yr. 2 - $83 million Yr. 3 - $69 million
Other revenue sources	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $28 million; Yr. 2 - $47 million; and Yr. 3 - $64 million.
Revenue decoupling mechanism	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $376 million; Yr. 2 - $383 million; and Yr. 3 - $395 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes(b), municipal infrastructure support costs(c), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(d)
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $21,689 million; Yr. 2 - $22,338 million; Yr. 3 - $23,002 million AMI: Yr. 1 - $126 million; Yr. 2 - $257 million; Yr. 3 - $415 million
Average rate base	Yr. 1 - $18,902 million Yr. 2 - $19,530 million Yr. 3 - $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.00 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent

(a) The electric base rate increases shown above are in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the current rate plan. At the NYSPSC’s option, these increases may be implemented with increases of $199 million in each rate year.

(b) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(c) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral of 30 percent of the amount reflected in rates.

(d) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers.

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

CECONY - Gas

In September 2016, CECONY, the staff of the NYSPSC and other parties entered into a Joint Proposal for a CECONY gas rate plan for the three-year period January 2017 through December 2019. The Joint Proposal is subject to NYSPSC approval. The following table contains a summary of the gas rate plan.

Effective period	January 2017 - December 2019
Base rate changes	Yr. 1 - $(5) million(a) Yr. 2 - $92 million Yr. 3 - $90 million
Amortizations to income of net regulatory (assets) liabilities	Yr. 1 - $39 million Yr. 2 - $37 million Yr. 3 - $36 million
Other revenue sources	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 - $7 million; Yr. 2 - $8 million; and Yr. 3 - $8 million.
Revenue decoupling mechanism	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 - $68 million; Yr. 2 - $75 million; and Yr. 3 - $83 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(b)
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $5,844 million; Yr. 2 - $6,512 million; Yr. 3 - $7,177 million AMI: Yr. 1 - $27 million; Yr. 2 - $57 million; Yr. 3 - $100 million
Average rate base	Yr. 1 - $4,841 million Yr. 2 - $5,395 million Yr. 3 - $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.00 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent

(a) The base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the current rate plan.

(b) See footnotes (b), (c) and (d) to the table under “CECONY-Electric,” above.

Rockland Electric Company (RECO)

In April 2016, RECO filed a request with the New Jersey Board of Public Utilities for an electric rate increase of $10 million, effective March 2017. The filing reflected a return on common equity of 10.20 percent and a common equity ratio of 49.81 percent. In October 2016, RECO filed an update to its April 2016 request. The company decreased its requested March 2017 rate increase by $4 million to $6 million. The updated filing reflects a return on common equity of 10.20 percent and a common equity ratio of 50.15 percent. The filing reflects continuation of provisions pursuant to which the company recovers its purchased power and fuel costs from customers. 

Other Regulatory Matters

In April 2016, the NYSPSC approved the September 2015 Joint Proposal among CECONY, the NYSPSC staff and others with respect to the prudence proceeding the NYSPSC commenced in February 2009 and related matters. Pursuant to the Joint Proposal, the company is required to credit $116 million to customers and, for the period 2017 through 2044, to not seek to recover from customers an aggregate $55 million relating to return on its capital expenditures. In addition, the company’s revenues that were made subject to potential refund in this proceeding are no longer subject to refund. At September 30, 2016, the company had a $96 million regulatory liability for the remaining amount to be credited to customers related to this matter.

In June 2014, the NYSPSC initiated a proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. New York State regulations require gas utilities to qualify and, except in certain circumstances, annually requalify workers that perform fusion to join plastic pipe. The NYSPSC directed the New York gas utilities to provide information in this proceeding about their compliance with the qualification and requalification requirements and related matters; their procedures for compliance with all gas safety regulations; and their annual chief executive officer certifications regarding these and other procedures. CECONY’s qualification and requalification procedures had not included certain required testing to evaluate specimen fuses. In addition, CECONY and O&R had not timely requalified certain workers that had been qualified under their respective procedures to perform fusion to join plastic pipe. CECONY and O&R have requalified their workers who perform plastic pipe fusions. In May 2015, the NYSPSC, which indicated that it would address enforcement at a later date, ordered CECONY, O&R and other gas utilities to perform risk assessment and remediation plans, additional leakage surveying and reporting; CECONY to hire an independent statistician to develop a risk assessment and remediation plan; and the gas utilities to implement certain new plastic fusion requirements. In December 2015, the NYSPSC staff informed O&R that the company had satisfactorily completed its risk assessment and remediation plan. CECONY submitted its risk assessment and remediation plan to the NYSPSC staff in October 2016.

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

At September 30, 2016, CECONY had a $28 million regulatory liability related to the June 2014 plastic fusion proceeding and the November 2015 order to show cause. The company is unable to estimate the amount or range of its possible loss related to these matters in excess of this regulatory liability.

CECONY has incurred costs for gas emergency response activities in 2014, 2015 and 2016 in excess of amounts reflected in the company’s gas rate plan. The company has requested NYSPSC authorization to defer as a regulatory asset $29 million and $35 million of such incremental costs incurred in 2014 and 2015, respectively. The company estimates that it will incur $37 million of such incremental costs in 2016. At September 30, 2016, the company had not deferred any such incremental costs.

Regulatory Assets and Liabilities

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$3,369	$3,876	$3,220	$3,697
Future income tax	2,429	2,350	2,312	2,232
Environmental remediation costs	823	904	720	800
Revenue taxes	298	253	283	240
Deferred storm costs	89	185	30	110
Deferred derivative losses	55	50	49	46
Unamortized loss on reacquired debt	45	50	43	48
Surcharge for New York State assessment	43	44	40	40
O&R property tax reconciliation	39	46	—	—
Pension and other postretirement benefits deferrals	34	45	3	16
Net electric deferrals	29	44	29	44
Preferred stock redemption	25	26	25	26
O&R transition bond charges	16	21	—	—
Workers’ compensation	15	11	15	11
Recoverable energy costs	7	16	5	15
Other	228	175	212	157
Regulatory assets – noncurrent	7,544	8,096	6,986	7,482
Deferred derivative losses	94	113	87	103
Recoverable energy costs	25	19	24	18
Regulatory assets – current	119	132	111	121
Total Regulatory Assets	$7,663	$8,228	$7,097	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$713	$676	$602	$570
Property tax reconciliation	205	303	205	303
Pension and other postretirement benefit deferrals	163	76	130	46
Net unbilled revenue deferrals	121	109	121	109
Prudence proceeding	96	99	96	99
Unrecognized other postretirement costs	91	28	91	28
New York State income tax rate change	66	75	64	72
Base rate change deferrals	62	128	62	128
Variable-rate tax-exempt debt – cost rate reconciliation	60	70	52	60
Carrying charges on repair allowance and bonus depreciation	57	49	56	48
Earnings sharing - electric, gas and steam	34	80	26	80
Net utility plant reconciliations	27	32	27	31
Property tax refunds	12	44	12	44
World Trade Center settlement proceeds	5	21	5	21
Other	208	187	176	150
Regulatory liabilities – noncurrent	1,920	1,977	1,725	1,789
Revenue decoupling mechanism	74	45	70	45
Refundable energy costs	37	64	18	33
Deferred derivative gains	12	6	8	6
Regulatory liabilities – current	123	115	96	84
Total Regulatory Liabilities	$2,043	$2,092	$1,821	$1,873

CECONY

Public Utilities, General Disclosures [Line Items]

Regulatory Matters

Regulatory Matters

Rate Plans

CECONY - Electric

In September 2016, CECONY, the staff of the New York State Public Service Commission (NYSPSC) and other parties entered into a Joint Proposal for a CECONY electric rate plan for the three-year period January 2017 through December 2019. The Joint Proposal is subject to NYSPSC approval. The following table contains a summary of the electric rate plan.

Effective period	January 2017 - December 2019
Base rate changes (a)	Yr. 1 - $195 million Yr. 2 - $155 million Yr. 3 - $155 million
Amortizations to income of net regulatory (assets) liabilities	Yr. 1 - $84 million Yr. 2 - $83 million Yr. 3 - $69 million
Other revenue sources	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $28 million; Yr. 2 - $47 million; and Yr. 3 - $64 million.
Revenue decoupling mechanism	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $376 million; Yr. 2 - $383 million; and Yr. 3 - $395 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes(b), municipal infrastructure support costs(c), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(d)
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $21,689 million; Yr. 2 - $22,338 million; Yr. 3 - $23,002 million AMI: Yr. 1 - $126 million; Yr. 2 - $257 million; Yr. 3 - $415 million
Average rate base	Yr. 1 - $18,902 million Yr. 2 - $19,530 million Yr. 3 - $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.00 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent

(a) The electric base rate increases shown above are in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the current rate plan. At the NYSPSC’s option, these increases may be implemented with increases of $199 million in each rate year.

(b) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(c) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral of 30 percent of the amount reflected in rates.

(d) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers.

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

CECONY - Gas

In September 2016, CECONY, the staff of the NYSPSC and other parties entered into a Joint Proposal for a CECONY gas rate plan for the three-year period January 2017 through December 2019. The Joint Proposal is subject to NYSPSC approval. The following table contains a summary of the gas rate plan.

Effective period	January 2017 - December 2019
Base rate changes	Yr. 1 - $(5) million(a) Yr. 2 - $92 million Yr. 3 - $90 million
Amortizations to income of net regulatory (assets) liabilities	Yr. 1 - $39 million Yr. 2 - $37 million Yr. 3 - $36 million
Other revenue sources	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 - $7 million; Yr. 2 - $8 million; and Yr. 3 - $8 million.
Revenue decoupling mechanism	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 - $68 million; Yr. 2 - $75 million; and Yr. 3 - $83 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(b)
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $5,844 million; Yr. 2 - $6,512 million; Yr. 3 - $7,177 million AMI: Yr. 1 - $27 million; Yr. 2 - $57 million; Yr. 3 - $100 million
Average rate base	Yr. 1 - $4,841 million Yr. 2 - $5,395 million Yr. 3 - $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.00 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent

(a) The base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the current rate plan.

(b) See footnotes (b), (c) and (d) to the table under “CECONY-Electric,” above.

Rockland Electric Company (RECO)

In April 2016, RECO filed a request with the New Jersey Board of Public Utilities for an electric rate increase of $10 million, effective March 2017. The filing reflected a return on common equity of 10.20 percent and a common equity ratio of 49.81 percent. In October 2016, RECO filed an update to its April 2016 request. The company decreased its requested March 2017 rate increase by $4 million to $6 million. The updated filing reflects a return on common equity of 10.20 percent and a common equity ratio of 50.15 percent. The filing reflects continuation of provisions pursuant to which the company recovers its purchased power and fuel costs from customers. 

Other Regulatory Matters

In April 2016, the NYSPSC approved the September 2015 Joint Proposal among CECONY, the NYSPSC staff and others with respect to the prudence proceeding the NYSPSC commenced in February 2009 and related matters. Pursuant to the Joint Proposal, the company is required to credit $116 million to customers and, for the period 2017 through 2044, to not seek to recover from customers an aggregate $55 million relating to return on its capital expenditures. In addition, the company’s revenues that were made subject to potential refund in this proceeding are no longer subject to refund. At September 30, 2016, the company had a $96 million regulatory liability for the remaining amount to be credited to customers related to this matter.

In June 2014, the NYSPSC initiated a proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. New York State regulations require gas utilities to qualify and, except in certain circumstances, annually requalify workers that perform fusion to join plastic pipe. The NYSPSC directed the New York gas utilities to provide information in this proceeding about their compliance with the qualification and requalification requirements and related matters; their procedures for compliance with all gas safety regulations; and their annual chief executive officer certifications regarding these and other procedures. CECONY’s qualification and requalification procedures had not included certain required testing to evaluate specimen fuses. In addition, CECONY and O&R had not timely requalified certain workers that had been qualified under their respective procedures to perform fusion to join plastic pipe. CECONY and O&R have requalified their workers who perform plastic pipe fusions. In May 2015, the NYSPSC, which indicated that it would address enforcement at a later date, ordered CECONY, O&R and other gas utilities to perform risk assessment and remediation plans, additional leakage surveying and reporting; CECONY to hire an independent statistician to develop a risk assessment and remediation plan; and the gas utilities to implement certain new plastic fusion requirements. In December 2015, the NYSPSC staff informed O&R that the company had satisfactorily completed its risk assessment and remediation plan. CECONY submitted its risk assessment and remediation plan to the NYSPSC staff in October 2016.

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

At September 30, 2016, CECONY had a $28 million regulatory liability related to the June 2014 plastic fusion proceeding and the November 2015 order to show cause. The company is unable to estimate the amount or range of its possible loss related to these matters in excess of this regulatory liability.

CECONY has incurred costs for gas emergency response activities in 2014, 2015 and 2016 in excess of amounts reflected in the company’s gas rate plan. The company has requested NYSPSC authorization to defer as a regulatory asset $29 million and $35 million of such incremental costs incurred in 2014 and 2015, respectively. The company estimates that it will incur $37 million of such incremental costs in 2016. At September 30, 2016, the company had not deferred any such incremental costs.

Regulatory Assets and Liabilities

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$3,369	$3,876	$3,220	$3,697
Future income tax	2,429	2,350	2,312	2,232
Environmental remediation costs	823	904	720	800
Revenue taxes	298	253	283	240
Deferred storm costs	89	185	30	110
Deferred derivative losses	55	50	49	46
Unamortized loss on reacquired debt	45	50	43	48
Surcharge for New York State assessment	43	44	40	40
O&R property tax reconciliation	39	46	—	—
Pension and other postretirement benefits deferrals	34	45	3	16
Net electric deferrals	29	44	29	44
Preferred stock redemption	25	26	25	26
O&R transition bond charges	16	21	—	—
Workers’ compensation	15	11	15	11
Recoverable energy costs	7	16	5	15
Other	228	175	212	157
Regulatory assets – noncurrent	7,544	8,096	6,986	7,482
Deferred derivative losses	94	113	87	103
Recoverable energy costs	25	19	24	18
Regulatory assets – current	119	132	111	121
Total Regulatory Assets	$7,663	$8,228	$7,097	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$713	$676	$602	$570
Property tax reconciliation	205	303	205	303
Pension and other postretirement benefit deferrals	163	76	130	46
Net unbilled revenue deferrals	121	109	121	109
Prudence proceeding	96	99	96	99
Unrecognized other postretirement costs	91	28	91	28
New York State income tax rate change	66	75	64	72
Base rate change deferrals	62	128	62	128
Variable-rate tax-exempt debt – cost rate reconciliation	60	70	52	60
Carrying charges on repair allowance and bonus depreciation	57	49	56	48
Earnings sharing - electric, gas and steam	34	80	26	80
Net utility plant reconciliations	27	32	27	31
Property tax refunds	12	44	12	44
World Trade Center settlement proceeds	5	21	5	21
Other	208	187	176	150
Regulatory liabilities – noncurrent	1,920	1,977	1,725	1,789
Revenue decoupling mechanism	74	45	70	45
Refundable energy costs	37	64	18	33
Deferred derivative gains	12	6	8	6
Regulatory liabilities – current	123	115	96	84
Total Regulatory Liabilities	$2,043	$2,092	$1,821	$1,873

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Capitalization

9 Months Ended

Sep. 30, 2016

Debt Instrument [Line Items]

Capitalization

Capitalization

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

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

In September 2016, CECONY redeemed at maturity $400 million aggregate principal amount of 5.50 percent debentures. In September 2016, O&R agreed to issue and sell for delivery in December 2016 $75 million aggregate principal amount of 3.88 percent debentures, due 2046. In October 2016, O&R redeemed at maturity $75 million aggregate principal amount of 5.45 percent debentures.

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

(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,093	$16,325	$12,745	$13,856
CECONY	$11,584	$13,564	$11,437	$12,427

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $15,689 million and $636 million of the fair value of long-term debt at September 30, 2016 are classified as Level 2 and Level 3, respectively. For CECONY, $12,928 million and $636 million of the fair value of long-term debt at September 30, 2016 are classified as Level 2 and Level 3, respectively (see Note L). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

CECONY

Debt Instrument [Line Items]

Capitalization

Capitalization

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

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

In September 2016, CECONY redeemed at maturity $400 million aggregate principal amount of 5.50 percent debentures. In September 2016, O&R agreed to issue and sell for delivery in December 2016 $75 million aggregate principal amount of 3.88 percent debentures, due 2046. In October 2016, O&R redeemed at maturity $75 million aggregate principal amount of 5.45 percent debentures.

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

(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,093	$16,325	$12,745	$13,856
CECONY	$11,584	$13,564	$11,437	$12,427

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $15,689 million and $636 million of the fair value of long-term debt at September 30, 2016 are classified as Level 2 and Level 3, respectively. For CECONY, $12,928 million and $636 million of the fair value of long-term debt at September 30, 2016 are classified as Level 2 and Level 3, respectively (see Note L). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

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Short-Term Borrowing

9 Months Ended

Sep. 30, 2016

Short-Term Borrowing

Short-Term Borrowing

At September 30, 2016, Con Edison had $601 million of commercial paper outstanding of which $480 million was outstanding under CECONY’s program. The weighted average interest rate at September 30, 2016 was 0.7 percent for both Con Edison and CECONY. At December 31, 2015, Con Edison had $1,529 million of commercial paper outstanding of which $1,033 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2015 was 0.7 percent for both Con Edison and CECONY.

At September 30, 2016 and December 31, 2015, no loans were outstanding under the credit agreement (Credit Agreement) and $2 million (including $2 million for CECONY) and $15 million of letters of credit were outstanding under the Credit Agreement, respectively.

CECONY

Short-Term Borrowing

Short-Term Borrowing

At September 30, 2016, Con Edison had $601 million of commercial paper outstanding of which $480 million was outstanding under CECONY’s program. The weighted average interest rate at September 30, 2016 was 0.7 percent for both Con Edison and CECONY. At December 31, 2015, Con Edison had $1,529 million of commercial paper outstanding of which $1,033 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2015 was 0.7 percent for both Con Edison and CECONY.

At September 30, 2016 and December 31, 2015, no loans were outstanding under the credit agreement (Credit Agreement) and $2 million (including $2 million for CECONY) and $15 million of letters of credit were outstanding under the Credit Agreement, respectively.

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Pension Benefits

9 Months Ended

Sep. 30, 2016

Defined Benefit Plan Disclosure [Line Items]

Pension Benefits

Pension Benefits

Total Periodic Benefit Cost

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$69	$74	$65	$70
Interest cost on projected benefit obligation	149	144	140	135
Expected return on plan assets	(237)	(222)	(225)	(210)
Recognition of net actuarial loss	149	194	141	183
Recognition of prior service costs	1	1	—	—
NET PERIODIC BENEFIT COST	$131	$191	$121	$178
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$131	$192	$121	$179
Cost capitalized	(51)	(80)	(49)	(76)
Reconciliation to rate level	10	(14)	13	(14)
Cost charged to operating expenses	$90	$98	$85	$89

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$207	$223	$194	$209
Interest cost on projected benefit obligation	447	431	419	404
Expected return on plan assets	(711)	(664)	(674)	(630)
Recognition of net actuarial loss	447	581	424	550
Recognition of prior service costs	3	3	1	1
NET PERIODIC BENEFIT COST	$393	$574	$364	$534
Amortization of regulatory asset	—	2	—	2
TOTAL PERIODIC BENEFIT COST	$393	$576	$364	$536
Cost capitalized	(157)	(224)	(148)	(214)
Reconciliation to rate level	35	(56)	39	(56)
Cost charged to operating expenses	$271	$296	$255	$266

Expected Contributions

Based on estimates as of September 30, 2016, the Companies expect to make contributions to the pension plans during 2016 of $508 million (of which $469 million is to be contributed by CECONY). The Companies’ policy is to fund the total periodic benefit cost of the qualified plan to the extent tax deductible and to also contribute to the non-qualified supplemental plans. During the first nine months of 2016, the Companies contributed $504 million (of which $466 million was contributed by CECONY) to the pension plans. CECONY also contributed $17 million to its external trust for supplemental plans.

CECONY

Defined Benefit Plan Disclosure [Line Items]

Pension Benefits

Pension Benefits

Total Periodic Benefit Cost

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$69	$74	$65	$70
Interest cost on projected benefit obligation	149	144	140	135
Expected return on plan assets	(237)	(222)	(225)	(210)
Recognition of net actuarial loss	149	194	141	183
Recognition of prior service costs	1	1	—	—
NET PERIODIC BENEFIT COST	$131	$191	$121	$178
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$131	$192	$121	$179
Cost capitalized	(51)	(80)	(49)	(76)
Reconciliation to rate level	10	(14)	13	(14)
Cost charged to operating expenses	$90	$98	$85	$89

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$207	$223	$194	$209
Interest cost on projected benefit obligation	447	431	419	404
Expected return on plan assets	(711)	(664)	(674)	(630)
Recognition of net actuarial loss	447	581	424	550
Recognition of prior service costs	3	3	1	1
NET PERIODIC BENEFIT COST	$393	$574	$364	$534
Amortization of regulatory asset	—	2	—	2
TOTAL PERIODIC BENEFIT COST	$393	$576	$364	$536
Cost capitalized	(157)	(224)	(148)	(214)
Reconciliation to rate level	35	(56)	39	(56)
Cost charged to operating expenses	$271	$296	$255	$266

Expected Contributions

Based on estimates as of September 30, 2016, the Companies expect to make contributions to the pension plans during 2016 of $508 million (of which $469 million is to be contributed by CECONY). The Companies’ policy is to fund the total periodic benefit cost of the qualified plan to the extent tax deductible and to also contribute to the non-qualified supplemental plans. During the first nine months of 2016, the Companies contributed $504 million (of which $466 million was contributed by CECONY) to the pension plans. CECONY also contributed $17 million to its external trust for supplemental plans.

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Other Postretirement Benefits

9 Months Ended

Sep. 30, 2016

Defined Benefit Plan Disclosure [Line Items]

Other Postretirement Benefits

Other Postretirement Benefits

Total Periodic Benefit Cost

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

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

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost	$13	$15	$10	$11
Interest cost on accumulated other postretirement benefit obligation	36	38	30	32
Expected return on plan assets	(58)	(59)	(50)	(51)
Recognition of net actuarial loss	4	24	2	21
Recognition of prior service cost	(15)	(15)	(11)	(10)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(20)	$3	$(19)	$3
Cost capitalized	5	(2)	5	(2)
Reconciliation to rate level	20	12	19	5
Cost charged to operating expenses	$5	$13	$5	$6

Contributions

During the first nine months of 2016, the Companies contributed $6 million, nearly all of which was contributed by CECONY, to the other postretirement benefit plans. The Companies' policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

CECONY

Defined Benefit Plan Disclosure [Line Items]

Other Postretirement Benefits

Other Postretirement Benefits

Total Periodic Benefit Cost

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

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

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost	$13	$15	$10	$11
Interest cost on accumulated other postretirement benefit obligation	36	38	30	32
Expected return on plan assets	(58)	(59)	(50)	(51)
Recognition of net actuarial loss	4	24	2	21
Recognition of prior service cost	(15)	(15)	(11)	(10)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(20)	$3	$(19)	$3
Cost capitalized	5	(2)	5	(2)
Reconciliation to rate level	20	12	19	5
Cost charged to operating expenses	$5	$13	$5	$6

Contributions

During the first nine months of 2016, the Companies contributed $6 million, nearly all of which was contributed by CECONY, to the other postretirement benefit plans. 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

9 Months Ended

Sep. 30, 2016

Site Contingency [Line Items]

Environmental Matters

Environmental Matters

Superfund Sites

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

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

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

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$664	$679	$574	$579
Other Superfund Sites	88	86	87	86
Total	$752	$765	$661	$665
Regulatory assets	$823	$904	$720	$800

Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The Companies are unable to estimate the time period over which the remaining accrued liability will be incurred because, among other things, the required remediation has not been determined for some of the sites. Under their current rate plans, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs.

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$8	$6	$5	$6

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$20	$21	$10	$18

Con Edison and CECONY received $1 million in insurance recoveries for the three and nine months ended September 30, 2016. No insurance recoveries were received by Con Edison or CECONY for the three and nine months ended September 30, 2015.

In 2015, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $2.8 billion and $2.7 billion, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different.

Asbestos Proceedings

Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, which are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At September 30, 2016, Con Edison and CECONY had accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. The estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Trial courts have begun, and unless otherwise determined by an appellate court may continue, to apply a different standard for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. Under its current rate plans, CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims.

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at September 30, 2016 and December 31, 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$90	$86	$85	$81
Regulatory assets – workers’ compensation	$15	$11	$15	$11

CECONY

Site Contingency [Line Items]

Environmental Matters

Environmental Matters

Superfund Sites

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

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

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

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$664	$679	$574	$579
Other Superfund Sites	88	86	87	86
Total	$752	$765	$661	$665
Regulatory assets	$823	$904	$720	$800

Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The Companies are unable to estimate the time period over which the remaining accrued liability will be incurred because, among other things, the required remediation has not been determined for some of the sites. Under their current rate plans, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs.

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$8	$6	$5	$6

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$20	$21	$10	$18

Con Edison and CECONY received $1 million in insurance recoveries for the three and nine months ended September 30, 2016. No insurance recoveries were received by Con Edison or CECONY for the three and nine months ended September 30, 2015.

In 2015, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $2.8 billion and $2.7 billion, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different.

Asbestos Proceedings

Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, which are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At September 30, 2016, Con Edison and CECONY had accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. The estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Trial courts have begun, and unless otherwise determined by an appellate court may continue, to apply a different standard for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. Under its current rate plans, CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims.

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at September 30, 2016 and December 31, 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$90	$86	$85	$81
Regulatory assets – workers’ compensation	$15	$11	$15	$11

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Other Material Contingencies

9 Months Ended

Sep. 30, 2016

Guarantor Obligations [Line Items]

Other Material Contingencies

Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately sixty suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs to satisfy its liability to others in connection with the suits. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At September 30, 2016, the company has accrued its estimated liability for the suits of $30 million and an insurance receivable of $39 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 Street in Manhattan were destroyed by an explosion and fire. CECONY had delivered gas to the buildings through service lines from a distribution main located below ground on Park Avenue. Eight people died and more than 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC (which also conducted an investigation). In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. Approximately seventy 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 September 30, 2016, the company had not accrued a liability for damages related to the incident.

Other Contingencies

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

Guarantees

Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled $2,422 million and $2,856 million at September 30, 2016 and December 31, 2015, respectively.

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

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$618	$430		$—	$1,048
Energy transactions	635	57	91		783
Renewable electric production projects	445	—	18		463
Other	128	—	—		128
Total	$1,826	$487	$109		$2,422

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

Energy Transactions — Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Guarantee amounts shown above include $123 million of guarantees or other credit support 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. See Note P. As part of the sale agreement, the purchaser has agreed to pay Con Edison Solutions for draws on such guarantees or other credit support.

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

Other — Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects and operation of solar energy facilities of Con Edison Solutions and Con Edison Development, respectively. Other guarantees also includes Con Edison's guarantee (subject to a $53 million maximum amount) of certain obligations of Con Edison Solutions under its agreement to sell its retail electric supply business. See Note P. 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.

CECONY

Guarantor Obligations [Line Items]

Other Material Contingencies

Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately sixty suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs to satisfy its liability to others in connection with the suits. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At September 30, 2016, the company has accrued its estimated liability for the suits of $30 million and an insurance receivable of $39 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 Street in Manhattan were destroyed by an explosion and fire. CECONY had delivered gas to the buildings through service lines from a distribution main located below ground on Park Avenue. Eight people died and more than 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC (which also conducted an investigation). In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. Approximately seventy 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 September 30, 2016, the company had not accrued a liability for damages related to the incident.

Other Contingencies

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

Guarantees

Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled $2,422 million and $2,856 million at September 30, 2016 and December 31, 2015, respectively.

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

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$618	$430		$—	$1,048
Energy transactions	635	57	91		783
Renewable electric production projects	445	—	18		463
Other	128	—	—		128
Total	$1,826	$487	$109		$2,422

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

Energy Transactions — Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Guarantee amounts shown above include $123 million of guarantees or other credit support 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. See Note P. As part of the sale agreement, the purchaser has agreed to pay Con Edison Solutions for draws on such guarantees or other credit support.

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

Other — Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects and operation of solar energy facilities of Con Edison Solutions and Con Edison Development, respectively. Other guarantees also includes Con Edison's guarantee (subject to a $53 million maximum amount) of certain obligations of Con Edison Solutions under its agreement to sell its retail electric supply business. See Note P. 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

9 Months Ended

Sep. 30, 2016

Income Tax Examination [Line Items]

Income Tax

Income Tax

Con Edison’s income tax expense increased to $314 million for the three months ended September 30, 2016 from $249 million for the three months ended September 30, 2015. Con Edison's effective tax rate for the three months ended September 30, 2016 and 2015 was 39 percent and 37 percent, respectively. The increase in Con Edison's effective tax rate is primarily due to higher state income taxes and a decrease in tax benefits for plant-related flow through items, offset in part by higher tax benefits for injuries and damages payments, research and development tax credits and renewable energy tax credits.

CECONY’s income tax expense increased to $226 million for the three months ended September 30, 2016 from $222 million for the three months ended September 30, 2015. CECONY's effective tax rate for the three months ended September 30, 2016 and 2015 was 37 percent. The decrease in tax benefits for plant-related flow through items, were more than offset by lower state income taxes and increased tax benefits as a result of higher injuries and damages payments and research and development tax credits.

Con Edison’s income tax expense increased to $602 million for the nine months ended September 30, 2016 from $548 million for the nine months ended September 30, 2015. Con Edison's effective tax rate for the nine months ended September 30, 2016 and 2015 was 37 percent and 35 percent, respectively. The increase in Con Edison's effective tax rate is primarily due to higher state income taxes and a decrease in tax benefits for plant-related flow through items, offset in part by higher tax benefits for injuries and damages payments, research and development tax credits and renewable energy tax credits.

CECONY’s income tax expense decreased to $491 million for the nine months ended September 30, 2016 from $515 million for the nine months ended September 30, 2015. CECONY's effective tax rate for the nine months ended September 30, 2016 and 2015 was 36 percent and 35 percent, respectively. The increase in CECONY's effective tax rate is primarily related to a decrease in tax benefits for plant-related flow through items, offset in part by lower state income taxes and increased research and development tax credits.

In September 2016, Con Edison filed its 2015 federal income tax return, requesting a refund of $19 million of estimated tax payments and, in October 2016, the company received the refund. The company carried back a 2015 net operating loss to 2007, requesting a refund of $16 million of federal income tax and, in October 2016, the company received the refund. Con Edison anticipates a federal net operating loss for 2016, primarily due to bonus depreciation. Con Edison expects to carryback a portion of its 2016 net operating loss and recover $32 million of income tax. General business tax credits that became available as a result of the net operating loss carryback, as well as the remaining 2016 net operating loss will be carried forward to future tax years. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized.

Uncertain Tax Positions

At September 30, 2016, the estimated liability for uncertain tax positions for Con Edison was $37 million ($5 million for CECONY). Con Edison reasonably expects to resolve approximately $29 million ($20 million, net of federal taxes) of its uncertain tax positions within the next twelve months, of which the entire amount, if recognized, would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $5 million ($4 million, net of federal taxes), of which the entire amount, if recognized, would reduce CECONY’s effective tax rate. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $37 million ($25 million, net of federal taxes).

The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In the three and nine months ended September 30, 2016, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At September 30, 2016 and December 31, 2015, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

CECONY

Income Tax Examination [Line Items]

Income Tax

Income Tax

Con Edison’s income tax expense increased to $314 million for the three months ended September 30, 2016 from $249 million for the three months ended September 30, 2015. Con Edison's effective tax rate for the three months ended September 30, 2016 and 2015 was 39 percent and 37 percent, respectively. The increase in Con Edison's effective tax rate is primarily due to higher state income taxes and a decrease in tax benefits for plant-related flow through items, offset in part by higher tax benefits for injuries and damages payments, research and development tax credits and renewable energy tax credits.

CECONY’s income tax expense increased to $226 million for the three months ended September 30, 2016 from $222 million for the three months ended September 30, 2015. CECONY's effective tax rate for the three months ended September 30, 2016 and 2015 was 37 percent. The decrease in tax benefits for plant-related flow through items, were more than offset by lower state income taxes and increased tax benefits as a result of higher injuries and damages payments and research and development tax credits.

Con Edison’s income tax expense increased to $602 million for the nine months ended September 30, 2016 from $548 million for the nine months ended September 30, 2015. Con Edison's effective tax rate for the nine months ended September 30, 2016 and 2015 was 37 percent and 35 percent, respectively. The increase in Con Edison's effective tax rate is primarily due to higher state income taxes and a decrease in tax benefits for plant-related flow through items, offset in part by higher tax benefits for injuries and damages payments, research and development tax credits and renewable energy tax credits.

CECONY’s income tax expense decreased to $491 million for the nine months ended September 30, 2016 from $515 million for the nine months ended September 30, 2015. CECONY's effective tax rate for the nine months ended September 30, 2016 and 2015 was 36 percent and 35 percent, respectively. The increase in CECONY's effective tax rate is primarily related to a decrease in tax benefits for plant-related flow through items, offset in part by lower state income taxes and increased research and development tax credits.

In September 2016, Con Edison filed its 2015 federal income tax return, requesting a refund of $19 million of estimated tax payments and, in October 2016, the company received the refund. The company carried back a 2015 net operating loss to 2007, requesting a refund of $16 million of federal income tax and, in October 2016, the company received the refund. Con Edison anticipates a federal net operating loss for 2016, primarily due to bonus depreciation. Con Edison expects to carryback a portion of its 2016 net operating loss and recover $32 million of income tax. General business tax credits that became available as a result of the net operating loss carryback, as well as the remaining 2016 net operating loss will be carried forward to future tax years. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized.

Uncertain Tax Positions

At September 30, 2016, the estimated liability for uncertain tax positions for Con Edison was $37 million ($5 million for CECONY). Con Edison reasonably expects to resolve approximately $29 million ($20 million, net of federal taxes) of its uncertain tax positions within the next twelve months, of which the entire amount, if recognized, would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $5 million ($4 million, net of federal taxes), of which the entire amount, if recognized, would reduce CECONY’s effective tax rate. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $37 million ($25 million, net of federal taxes).

The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In the three and nine months ended September 30, 2016, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At September 30, 2016 and December 31, 2015, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

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Financial Information by Business Segment

9 Months Ended

Sep. 30, 2016

Segment Reporting Information [Line Items]

Financial Information by Business Segment

Financial Information by Business Segment

Con Edison’s principal business segments prior to June 2016 were CECONY’s regulated utility activities, O&R’s regulated utility activities and Con Edison’s competitive energy businesses. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. In 2016, Con Edison Transmission began investing, through CET Electric and CET Gas, in electric transmission and gas pipeline and storage assets (see Note P). As a result of these investments, in June 2016 Con Edison changed its business segments to add Con Edison Transmission as a separate reportable segment based on management’s reporting and decision-making, including performance evaluation and resource allocation. For comparison purposes, the previously reported financial information by business segments was reclassified to reflect the current business segment presentation.

The financial data for the business segments are as follows:

	As of and for the Three Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)		Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$2,557	$2,558	$5		$4		$217	$207	$841	$811	$2	$(2)	$117	$111	$275	$260	$30,580	$30,369	$411	$419
Gas	208	213	1		1		41	35	(28)	(17)	—	(1)	27	24	(24)	(17)	7,300	6,687	224	178
Steam	63	58	22		22		20	20	(47)	(49)	—	—	10	10	(17)	(18)	2,556	2,614	24	27
Consolidation adjustments	—	—	(28)		(27)		—	—	—	—	—	—	—	—	—	—	—	—	—	—
Total CECONY	$2,828	$2,829		$—		$—	$278	$262	$766	$745	$2	$(3)	$154	$145	$234	$225	$40,436	$39,670	$659	$624
O&R
Electric	$213	$205		$—		$—	$12	$13	$55	$51	$1	$(4)	$6	$6	$20	$17	$1,985	$1,959	$24	$26
Gas	27	24	—		—		5	4	(7)	(9)	—	(1)	3	3	(4)	(5)	799	754	14	12
Total O&R	$240	$229		$—		$—	$17	$17	$48	$42	$1	$(5)	$9	$9	$16	$12	$2,784	$2,713	$38	$38
Competitive energy businesses	$350	$386	$(2)		$(2)		$11	$6	$125	$43	$27	$17	$7	$2	$67	$21	$2,394	$1,547	$121	$212
Con Edison Transmission	—	—	—		—		—	—	(1)	—	20	—	3	—	—	—	1,072	2	—	—
Other (a)	(1)	(1)	2		2		(1)	—	2	—	(1)	—	5	6	4	2	630	1,039	—	—
Total Con Edison	$3,417	$3,443		$—		$—	$305	$285	$940	$830	$49	$9	$178	$162	$321	$260	$47,316	$44,971	$818	$874

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

	As of and for the Nine Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)		Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$6,222	$6,416	$13		$13		$645	$610	$1,487	$1,511	$3	$(3)	$342	$333	$412	$401	$30,580	$30,369	$1,133	$1,165
Gas	1,113	1,177	4		4		118	105	273	278	(1)	(1)	79	71	73	82	7,300	6,687	589	466
Steam	406	529	65		65		62	58	39	100	—	—	30	31	18	42	2,556	2,614	74	65
Consolidation adjustments	—	—	(82)		(82)		—	—	—	—	—	—	—	—	—	—	—	—	—	—
Total CECONY	$7,741	$8,122		$—		$—	$825	$773	$1,799	$1,889	$2	$(4)	$451	$435	$503	$525	$40,436	$39,670	$1,796	$1,696
O&R
Electric	$497	$523		$—		$—	$37	$38	$86	$85	$1	$(2)	$19	$18	$27	$26	$1,985	$1,959	$70	$72
Gas	133	117	—		—		13	13	28	—	—	(2)	9	9	8	(4)	799	754	36	29
Total O&R	$630	$640		$—		$—	$50	$51	$114	$85	$1	$(4)	$28	$27	$35	$22	$2,784	$2,713	$106	$101
Competitive energy businesses	$998	$1,087	$7		$(5)		$30	$16	$184	$53	$36	$33	$23	$5	$76	$24	$2,394	$1,547	$677	$676
Con Edison Transmission	—	—	—		—		—	—	(1)	—	23	—	4	—	—	—	1,072	2	—	—
Other (a)	(1)	(2)	(7)		5		—	—	1	1	(1)	(2)	11	19	6	3	630	1,039	—	—
Total Con Edison	$9,368	$9,847		$—		$—	$905	$840	$2,097	$2,028	$61	$23	$517	$486	$620	$574	$47,316	$44,971	$2,579	$2,473

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

CECONY

Segment Reporting Information [Line Items]

Financial Information by Business Segment

Financial Information by Business Segment

Con Edison’s principal business segments prior to June 2016 were CECONY’s regulated utility activities, O&R’s regulated utility activities and Con Edison’s competitive energy businesses. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. In 2016, Con Edison Transmission began investing, through CET Electric and CET Gas, in electric transmission and gas pipeline and storage assets (see Note P). As a result of these investments, in June 2016 Con Edison changed its business segments to add Con Edison Transmission as a separate reportable segment based on management’s reporting and decision-making, including performance evaluation and resource allocation. For comparison purposes, the previously reported financial information by business segments was reclassified to reflect the current business segment presentation.

The financial data for the business segments are as follows:

	As of and for the Three Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)		Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$2,557	$2,558	$5		$4		$217	$207	$841	$811	$2	$(2)	$117	$111	$275	$260	$30,580	$30,369	$411	$419
Gas	208	213	1		1		41	35	(28)	(17)	—	(1)	27	24	(24)	(17)	7,300	6,687	224	178
Steam	63	58	22		22		20	20	(47)	(49)	—	—	10	10	(17)	(18)	2,556	2,614	24	27
Consolidation adjustments	—	—	(28)		(27)		—	—	—	—	—	—	—	—	—	—	—	—	—	—
Total CECONY	$2,828	$2,829		$—		$—	$278	$262	$766	$745	$2	$(3)	$154	$145	$234	$225	$40,436	$39,670	$659	$624
O&R
Electric	$213	$205		$—		$—	$12	$13	$55	$51	$1	$(4)	$6	$6	$20	$17	$1,985	$1,959	$24	$26
Gas	27	24	—		—		5	4	(7)	(9)	—	(1)	3	3	(4)	(5)	799	754	14	12
Total O&R	$240	$229		$—		$—	$17	$17	$48	$42	$1	$(5)	$9	$9	$16	$12	$2,784	$2,713	$38	$38
Competitive energy businesses	$350	$386	$(2)		$(2)		$11	$6	$125	$43	$27	$17	$7	$2	$67	$21	$2,394	$1,547	$121	$212
Con Edison Transmission	—	—	—		—		—	—	(1)	—	20	—	3	—	—	—	1,072	2	—	—
Other (a)	(1)	(1)	2		2		(1)	—	2	—	(1)	—	5	6	4	2	630	1,039	—	—
Total Con Edison	$3,417	$3,443		$—		$—	$305	$285	$940	$830	$49	$9	$178	$162	$321	$260	$47,316	$44,971	$818	$874

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

	As of and for the Nine Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)		Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$6,222	$6,416	$13		$13		$645	$610	$1,487	$1,511	$3	$(3)	$342	$333	$412	$401	$30,580	$30,369	$1,133	$1,165
Gas	1,113	1,177	4		4		118	105	273	278	(1)	(1)	79	71	73	82	7,300	6,687	589	466
Steam	406	529	65		65		62	58	39	100	—	—	30	31	18	42	2,556	2,614	74	65
Consolidation adjustments	—	—	(82)		(82)		—	—	—	—	—	—	—	—	—	—	—	—	—	—
Total CECONY	$7,741	$8,122		$—		$—	$825	$773	$1,799	$1,889	$2	$(4)	$451	$435	$503	$525	$40,436	$39,670	$1,796	$1,696
O&R
Electric	$497	$523		$—		$—	$37	$38	$86	$85	$1	$(2)	$19	$18	$27	$26	$1,985	$1,959	$70	$72
Gas	133	117	—		—		13	13	28	—	—	(2)	9	9	8	(4)	799	754	36	29
Total O&R	$630	$640		$—		$—	$50	$51	$114	$85	$1	$(4)	$28	$27	$35	$22	$2,784	$2,713	$106	$101
Competitive energy businesses	$998	$1,087	$7		$(5)		$30	$16	$184	$53	$36	$33	$23	$5	$76	$24	$2,394	$1,547	$677	$676
Con Edison Transmission	—	—	—		—		—	—	(1)	—	23	—	4	—	—	—	1,072	2	—	—
Other (a)	(1)	(2)	(7)		5		—	—	1	1	(1)	(2)	11	19	6	3	630	1,039	—	—
Total Con Edison	$9,368	$9,847		$—		$—	$905	$840	$2,097	$2,028	$61	$23	$517	$486	$620	$574	$47,316	$44,971	$2,579	$2,473

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

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Derivative Instruments and Hedging Activities

9 Months Ended

Sep. 30, 2016

Derivative [Line Items]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the 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 September 30, 2016 and December 31, 2015 were:

(Millions of Dollars)	2016				2015
Balance Sheet Location	Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)		Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)
Con Edison
Fair value of derivative assets
Current	$75	$(60)	$15	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	58	(57)	1		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$133	$(117)	$16		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(143)	$73	$(70)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(111)	59	(52)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(254)	$132	$(122)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(121)	$15	$(106)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(46)	$6	(b)	$40	$(32)	$8	(b)
Noncurrent	45	(45)	—		48	(47)	1
Total fair value of derivative assets	$97	$(91)	$6		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(122)	$61	$(61)		$(121)	$71	$(50)
Noncurrent	(92)	47	(45)		(92)	56	(36)
Total fair value of derivative liabilities	$(214)	$108	$(106)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(117)	$17	$(100)	(b)	$(125)	$48	$(77)	(b)

(a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount.

(b) At September 30, 2016 and December 31, 2015, margin deposits for Con Edison ($12 million and $26 million, respectively) and CECONY ($12 million and $26 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

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

The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements. Con Edison’s competitive energy businesses record realized and unrealized gains and losses on their derivative contracts in purchased power, gas purchased for resale and non-utility revenue in the reporting period in which they occur. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2016 and 2015:

		For the Three Months Ended September 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(1)		$(1)		$(3)		$(1)
Noncurrent	Deferred derivative gains	(2)		—		—		—
Total deferred gains/(losses)		$(3)		$(1)		$(3)		$(1)
Current	Deferred derivative losses	$(19)		$8		$(18)		$8
Current	Recoverable energy costs	(39)		(53)		(35)		(49)
Noncurrent	Deferred derivative losses	(17)		14		(14)		13
Total deferred gains/(losses)		$(75)		$(31)		$(67)		$(28)
Net deferred gains/(losses)		$(78)		$(32)		$(70)		$(29)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(37)	(a)	$(31)	(b)		$—		$—
	Gas purchased for resale	(38)		(26)		—		—
	Non-utility revenue	(2)	(a)	5	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(77)		$(52)			$—		$—

(a) For the three months ended September 30, 2016, Con Edison recorded unrealized losses in non-utility operating revenue ($2 million) and purchase power expense ($23 million).

(b) For the three months ended September 30, 2015, Con Edison recorded in purchased power expense an unrealized pre-tax gain of $12 million.

		For the Nine Months Ended September 30,
		Con Edison					CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015			2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$6			$—		$2		$1
Noncurrent	Deferred derivative gains	(1)		—			(1)		—
Total deferred gains/(losses)		$5			$—		$1		$1
Current	Deferred derivative losses	$19		$40			$16		$40
Current	Recoverable energy costs	(163)		(92)			(148)		(87)
Noncurrent	Deferred derivative losses	(5)		(7)			(3)		(5)
Total deferred gains/(losses)		$(149)		$(59)			$(135)		$(52)
Net deferred gains/(losses)		$(144)		$(59)			$(134)		$(51)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(106)	(a)	$(60)		(b)		$—		$—
	Gas purchased for resale	(72)		(94)			—		—
	Non-utility revenue	15	(a)	20		(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(163)		$(134)				$—		$—

(a) For the nine months ended September 30, 2016, Con Edison recorded unrealized gains and losses in non-utility operating revenue ($3 million loss) and purchase power expense ($11 million gain).

(b) For the nine months ended September 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($3 million loss) and purchased power expense ($6 million gain).

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

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	22,797,395	15,472	69,954,738	1,344,000
CECONY	20,724,225	9,000	70,100,000	1,344,000

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

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

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

At September 30, 2016, Con Edison and CECONY had $141 million and $13 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $77 million with independent system operators, $34 million with investment-grade counterparties, $20 million with commodity exchange brokers, and $10 million with non-investment grade/non-rated counterparties. CECONY’s net credit exposure consisted of $12 million with commodity exchange brokers and $1 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 September 30, 2016:

(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$111		$97
Collateral posted	24		23
Additional collateral (b) (downgrade one level from current ratings)	18		15
Additional collateral (b) (downgrade to below investment grade from current ratings)	106	(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 competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $10 million at September 30, 2016. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) Derivative instruments that are net assets have been excluded from the table. At September 30, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $9 million.

CECONY

Derivative [Line Items]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the 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 September 30, 2016 and December 31, 2015 were:

(Millions of Dollars)	2016				2015
Balance Sheet Location	Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)		Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)
Con Edison
Fair value of derivative assets
Current	$75	$(60)	$15	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	58	(57)	1		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$133	$(117)	$16		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(143)	$73	$(70)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(111)	59	(52)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(254)	$132	$(122)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(121)	$15	$(106)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(46)	$6	(b)	$40	$(32)	$8	(b)
Noncurrent	45	(45)	—		48	(47)	1
Total fair value of derivative assets	$97	$(91)	$6		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(122)	$61	$(61)		$(121)	$71	$(50)
Noncurrent	(92)	47	(45)		(92)	56	(36)
Total fair value of derivative liabilities	$(214)	$108	$(106)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(117)	$17	$(100)	(b)	$(125)	$48	$(77)	(b)

(a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount.

(b) At September 30, 2016 and December 31, 2015, margin deposits for Con Edison ($12 million and $26 million, respectively) and CECONY ($12 million and $26 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

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

The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements. Con Edison’s competitive energy businesses record realized and unrealized gains and losses on their derivative contracts in purchased power, gas purchased for resale and non-utility revenue in the reporting period in which they occur. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2016 and 2015:

		For the Three Months Ended September 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(1)		$(1)		$(3)		$(1)
Noncurrent	Deferred derivative gains	(2)		—		—		—
Total deferred gains/(losses)		$(3)		$(1)		$(3)		$(1)
Current	Deferred derivative losses	$(19)		$8		$(18)		$8
Current	Recoverable energy costs	(39)		(53)		(35)		(49)
Noncurrent	Deferred derivative losses	(17)		14		(14)		13
Total deferred gains/(losses)		$(75)		$(31)		$(67)		$(28)
Net deferred gains/(losses)		$(78)		$(32)		$(70)		$(29)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(37)	(a)	$(31)	(b)		$—		$—
	Gas purchased for resale	(38)		(26)		—		—
	Non-utility revenue	(2)	(a)	5	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(77)		$(52)			$—		$—

(a) For the three months ended September 30, 2016, Con Edison recorded unrealized losses in non-utility operating revenue ($2 million) and purchase power expense ($23 million).

(b) For the three months ended September 30, 2015, Con Edison recorded in purchased power expense an unrealized pre-tax gain of $12 million.

		For the Nine Months Ended September 30,
		Con Edison					CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015			2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$6			$—		$2		$1
Noncurrent	Deferred derivative gains	(1)		—			(1)		—
Total deferred gains/(losses)		$5			$—		$1		$1
Current	Deferred derivative losses	$19		$40			$16		$40
Current	Recoverable energy costs	(163)		(92)			(148)		(87)
Noncurrent	Deferred derivative losses	(5)		(7)			(3)		(5)
Total deferred gains/(losses)		$(149)		$(59)			$(135)		$(52)
Net deferred gains/(losses)		$(144)		$(59)			$(134)		$(51)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(106)	(a)	$(60)		(b)		$—		$—
	Gas purchased for resale	(72)		(94)			—		—
	Non-utility revenue	15	(a)	20		(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(163)		$(134)				$—		$—

(a) For the nine months ended September 30, 2016, Con Edison recorded unrealized gains and losses in non-utility operating revenue ($3 million loss) and purchase power expense ($11 million gain).

(b) For the nine months ended September 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($3 million loss) and purchased power expense ($6 million gain).

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

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	22,797,395	15,472	69,954,738	1,344,000
CECONY	20,724,225	9,000	70,100,000	1,344,000

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

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

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

At September 30, 2016, Con Edison and CECONY had $141 million and $13 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $77 million with independent system operators, $34 million with investment-grade counterparties, $20 million with commodity exchange brokers, and $10 million with non-investment grade/non-rated counterparties. CECONY’s net credit exposure consisted of $12 million with commodity exchange brokers and $1 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 September 30, 2016:

(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$111		$97
Collateral posted	24		23
Additional collateral (b) (downgrade one level from current ratings)	18		15
Additional collateral (b) (downgrade to below investment grade from current ratings)	106	(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 competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $10 million at September 30, 2016. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) Derivative instruments that are net assets have been excluded from the table. At September 30, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $9 million.

XML

Fair Value Measurements

9 Months Ended

Sep. 30, 2016

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

Fair Value Measurements

Fair Value Measurements

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

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

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

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

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

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

	2016					2015
(Millions of Dollars)	Level 1	Level 2	Level 3	Netting Adjustment (e)	Total	Level 1	Level 2	Level 3		Netting Adjustment (e)	Total
Con Edison
Derivative assets:
Commodity (a)(b)(c)	$6	$21	$6	$(5)	$28	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	—	—	—	—	—	63	1		(63)	1
Other (a)(b)(d)	224	113	—	—	337	185	112	—		—	297
Total assets	$230	$134	$6	$(5)	$365	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$3	$146	$5	$(32)	$122	$16	$153	$1		$(65)	$105
Commodity held for sale (f)	—	—	—	—	—	1	133	7		(63)	78
Total liabilities	$3	$146	$5	$(32)	$122	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$4	$7	$1	$6	$18	$1	$9	$8		$17	$35
Other (a)(b)(d)	200	108	—	—	308	171	105	—		—	276
Total assets	$204	$115	$1	$6	$326	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$2	$126	$1	$(23)	$106	$14	$129		$—	$(57)	$86

(a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. There were no transfers between levels 1, 2 and 3 for the nine months ended September 30, 2016 and for the year ended December 31, 2015.

(b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.

(c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2016 and December 31, 2015, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.

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

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

(f) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet.

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

	Fair Value of Level 3 at September 30, 2016		Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
Con Edison – Commodity
Electricity	$(1)		Discounted Cash Flow	Forward energy prices (a)	$19.75-$80.00 per MWh
	1		Discounted Cash Flow	Forward capacity prices (a)	$2.68-$9.45 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)	52.8%-59.4%
				Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(44.9)%-58.9%
				Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(0.14)-$2.82 per MWh
Total Con Edison—Commodity	$1
CECONY—Commodity
Electricity	$(1)		Discounted Cash Flow	Forward energy prices (a)	$21.10-$80.00 per MWh
Transmission Congestion Contracts	$1		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
				Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(44.9)%-58.9%
Total CECONY—Commodity		$—

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

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

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of September 30, 2016 and 2015 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016		2015
Beginning balance as of July 1,	$5	$13	$2		$11
Included in earnings	(4)	(4)	—		(1)
Included in regulatory assets and liabilities	(5)	(1)	(3)		(1)
Purchases	—	1	—		1
Sales (a)	4	—	—		—
Settlements	1	(5)	1		(2)
Ending balance as of September 30,	$1	$4		$—	$8

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016		2015
Beginning balance as of January 1,	$6	$20	$8		$13
Included in earnings	(1)	(18)	(1)		(5)
Included in regulatory assets and liabilities	(11)	(1)	(6)		(1)
Purchases	2	9	1		5
Sales (a)	4	—	—		—
Settlements	1	(6)	(2)		(4)
Ending balance as of September 30,	$1	$4		$—	$8

(a) Amounts represent derivative instruments novated as part of the assets of Con Edison Solutions’ retail electric supply business which were sold to a subsidiary of Exelon Corporation (see Note P).

For the Utilities, realized gains and losses on Level 3 commodity derivative assets and liabilities are reported as part of purchased power, gas and fuel costs. The Utilities generally recover these costs in accordance with rate provisions approved by the applicable state public utilities regulators. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations.

For the competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues (immaterial for both periods) and purchased power costs ($5 millionloss and $3 millionloss) on the consolidated income statement for the three months ended September 30, 2016 and 2015, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues (immaterial for both periods) and purchased power costs ($6 millionloss and $12 millionloss) on the consolidated income statement for the nine months ended September 30, 2016, and 2015, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at September 30, 2016 and 2015 is included in non-utility revenues (immaterial for both periods) and purchased power costs ($4 millionloss and $3 millionloss) on the consolidated income statement for the three months ended September 30, 2016 and 2015, respectively. For the nine months ended September 30, 2016, and 2015, the change in fair value relating to Level 3 commodity derivative assets and liabilities is included in non-utility revenues (immaterial for both periods) and purchased power costs ($2 millionloss and $8 millionloss) on the consolidated income statement, respectively.

CECONY

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

Fair Value Measurements

Fair Value Measurements

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

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

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

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

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

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

	2016					2015
(Millions of Dollars)	Level 1	Level 2	Level 3	Netting Adjustment (e)	Total	Level 1	Level 2	Level 3		Netting Adjustment (e)	Total
Con Edison
Derivative assets:
Commodity (a)(b)(c)	$6	$21	$6	$(5)	$28	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	—	—	—	—	—	63	1		(63)	1
Other (a)(b)(d)	224	113	—	—	337	185	112	—		—	297
Total assets	$230	$134	$6	$(5)	$365	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$3	$146	$5	$(32)	$122	$16	$153	$1		$(65)	$105
Commodity held for sale (f)	—	—	—	—	—	1	133	7		(63)	78
Total liabilities	$3	$146	$5	$(32)	$122	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$4	$7	$1	$6	$18	$1	$9	$8		$17	$35
Other (a)(b)(d)	200	108	—	—	308	171	105	—		—	276
Total assets	$204	$115	$1	$6	$326	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$2	$126	$1	$(23)	$106	$14	$129		$—	$(57)	$86

(a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. There were no transfers between levels 1, 2 and 3 for the nine months ended September 30, 2016 and for the year ended December 31, 2015.

(b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.

(c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2016 and December 31, 2015, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.

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

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

(f) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet.

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

	Fair Value of Level 3 at September 30, 2016		Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
Con Edison – Commodity
Electricity	$(1)		Discounted Cash Flow	Forward energy prices (a)	$19.75-$80.00 per MWh
	1		Discounted Cash Flow	Forward capacity prices (a)	$2.68-$9.45 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)	52.8%-59.4%
				Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(44.9)%-58.9%
				Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(0.14)-$2.82 per MWh
Total Con Edison—Commodity	$1
CECONY—Commodity
Electricity	$(1)		Discounted Cash Flow	Forward energy prices (a)	$21.10-$80.00 per MWh
Transmission Congestion Contracts	$1		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
				Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(44.9)%-58.9%
Total CECONY—Commodity		$—

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

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

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of September 30, 2016 and 2015 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016		2015
Beginning balance as of July 1,	$5	$13	$2		$11
Included in earnings	(4)	(4)	—		(1)
Included in regulatory assets and liabilities	(5)	(1)	(3)		(1)
Purchases	—	1	—		1
Sales (a)	4	—	—		—
Settlements	1	(5)	1		(2)
Ending balance as of September 30,	$1	$4		$—	$8

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016		2015
Beginning balance as of January 1,	$6	$20	$8		$13
Included in earnings	(1)	(18)	(1)		(5)
Included in regulatory assets and liabilities	(11)	(1)	(6)		(1)
Purchases	2	9	1		5
Sales (a)	4	—	—		—
Settlements	1	(6)	(2)		(4)
Ending balance as of September 30,	$1	$4		$—	$8

(a) Amounts represent derivative instruments novated as part of the assets of Con Edison Solutions’ retail electric supply business which were sold to a subsidiary of Exelon Corporation (see Note P).

For the Utilities, realized gains and losses on Level 3 commodity derivative assets and liabilities are reported as part of purchased power, gas and fuel costs. The Utilities generally recover these costs in accordance with rate provisions approved by the applicable state public utilities regulators. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations.

For the competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues (immaterial for both periods) and purchased power costs ($5 millionloss and $3 millionloss) on the consolidated income statement for the three months ended September 30, 2016 and 2015, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues (immaterial for both periods) and purchased power costs ($6 millionloss and $12 millionloss) on the consolidated income statement for the nine months ended September 30, 2016, and 2015, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at September 30, 2016 and 2015 is included in non-utility revenues (immaterial for both periods) and purchased power costs ($4 millionloss and $3 millionloss) on the consolidated income statement for the three months ended September 30, 2016 and 2015, respectively. For the nine months ended September 30, 2016, and 2015, the change in fair value relating to Level 3 commodity derivative assets and liabilities is included in non-utility revenues (immaterial for both periods) and purchased power costs ($2 millionloss and $8 millionloss) on the consolidated income statement, respectively.

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Variable Interest Entities

9 Months Ended

Sep. 30, 2016

Schedule of Equity Method Investments [Line Items]

Variable Interest Entities

Variable Interest Entities

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

CECONY had a variable interest in a non-consolidated variable interest entity (VIE), Astoria Energy, LLC (Astoria Energy), with which CECONY entered into a long-term electricity purchase agreement that expired in April 2016. CECONY has ongoing long-term electricity purchase agreements with the following two potential VIEs: Cogen Technologies Linden Venture, LP, and Brooklyn Navy Yard Cogeneration Partners, LP. In 2015, requests were made of these two counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. The payments for these contracts constitute CECONY’s maximum exposure to loss with respect to the potential VIEs.

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

Project Name (a)	Generating Capacity (b) (MW AC)	Power Purchase Agreement Term (in Years)	Year of Initial Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (c)
Copper Mountain Solar 3	128	20	2014	Nevada	$179
Panoche Valley (d)	120	20	2015	California	274
Mesquite Solar 1	83	20	2013	Arizona	107
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	70
Broken Bow II	38	25	2014	Nebraska	51
Texas Solar 4	32	25	2014	Texas	43

(a) With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development. The maximum exposure for Texas Solar 4 is the net assets of the investment offset by an $8 million noncontrolling interest.

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

(c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet and any related receivables due from the project. For consolidated investments, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

(d) In October 2016, Con Edison Development acquired the remaining 50 percent ownership interest in the project. See Note P.

CECONY

Schedule of Equity Method Investments [Line Items]

Variable Interest Entities

Variable Interest Entities

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

CECONY had a variable interest in a non-consolidated variable interest entity (VIE), Astoria Energy, LLC (Astoria Energy), with which CECONY entered into a long-term electricity purchase agreement that expired in April 2016. CECONY has ongoing long-term electricity purchase agreements with the following two potential VIEs: Cogen Technologies Linden Venture, LP, and Brooklyn Navy Yard Cogeneration Partners, LP. In 2015, requests were made of these two counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. The payments for these contracts constitute CECONY’s maximum exposure to loss with respect to the potential VIEs.

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

Project Name (a)	Generating Capacity (b) (MW AC)	Power Purchase Agreement Term (in Years)	Year of Initial Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (c)
Copper Mountain Solar 3	128	20	2014	Nevada	$179
Panoche Valley (d)	120	20	2015	California	274
Mesquite Solar 1	83	20	2013	Arizona	107
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	70
Broken Bow II	38	25	2014	Nebraska	51
Texas Solar 4	32	25	2014	Texas	43

(a) With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development. The maximum exposure for Texas Solar 4 is the net assets of the investment offset by an $8 million noncontrolling interest.

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

(c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet and any related receivables due from the project. For consolidated investments, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

(d) In October 2016, Con Edison Development acquired the remaining 50 percent ownership interest in the project. See Note P.

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Related Party Transactions

9 Months Ended

Sep. 30, 2016

Related Party Transactions

Related Party Transactions

The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric has a 45.7 percent equity interest (see Note P). The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the three and nine months ended September 30, 2016, the amounts billed by CECONY to NY Transco were immaterial.

CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC (Stagecoach), a joint venture formed by a subsidiary of CET Gas and a subsidiary of Crestwood Equity Partners LP (Crestwood) (see Note P). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. For the three months ended September 30, 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $8 million. Since the formation of the joint venture in June 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $10 million.

CECONY has a financial electric capacity contract with Con Edison Energy for the period May 2016 through April 2017. For the three and nine months ended September 30, 2016, Con Edison Energy's realized losses under this contract were $1 million.

At September 30, 2016 Con Edison Development has an outstanding note receivable of $234 million from Panoche Valley, a solar electric production project in which Con Edison Development has an ownership interest of 50 percent (see Note M). In October 2016, Con Edison Development acquired the remaining 50 percent interest in the project (see Note P).

CECONY

Related Party Transactions

Related Party Transactions

The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric has a 45.7 percent equity interest (see Note P). The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the three and nine months ended September 30, 2016, the amounts billed by CECONY to NY Transco were immaterial.

CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC (Stagecoach), a joint venture formed by a subsidiary of CET Gas and a subsidiary of Crestwood Equity Partners LP (Crestwood) (see Note P). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. For the three months ended September 30, 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $8 million. Since the formation of the joint venture in June 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $10 million.

CECONY has a financial electric capacity contract with Con Edison Energy for the period May 2016 through April 2017. For the three and nine months ended September 30, 2016, Con Edison Energy's realized losses under this contract were $1 million.

At September 30, 2016 Con Edison Development has an outstanding note receivable of $234 million from Panoche Valley, a solar electric production project in which Con Edison Development has an ownership interest of 50 percent (see Note M). In October 2016, Con Edison Development acquired the remaining 50 percent interest in the project (see Note P).

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New Financial Accounting Standards

9 Months Ended

Sep. 30, 2016

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Financial Accounting Standards

New Financial Accounting Standards

In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board jointly issued a revenue recognition standard that will supersede the revenue recognition requirements within Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. Additionally, in March and April 2016, respectively, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations (Reporting Revenue Gross Versus Net)” to clarify how to apply the implementation guidance for principal versus agent considerations and ASU No. 2016-10,“Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing” to clarify the guidance pertaining to identifying performance obligations and licensing implementation guidance. Furthermore in May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” to clarify assessing collectibility, presentation of sales taxes, noncash consideration, contract modification at transition, and completed contracts at transition. The new standard is effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for reporting periods beginning after December 15, 2016. The Companies are in the process of evaluating the application and impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The

Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” This amendment requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments in this Update are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of the 2014-09 and 2014-16. The Companies are in the process of evaluating the potential impact of the amendments on the Companies’ financial position, results of operations and liquidity.

In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial

instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In August 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force).” The amendment specifies the classification and presentation of certain cash flow items to reduce diversity in practice. 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 October 2016, the FASB issued amendments to the guidance for Income Taxes through ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory.” The amendment clarifies the tax treatment of intra-entity transfers of assets other than inventory. The updated guidance requires entities recognize the income tax consequences of an intra-entity transfer of assets other than inventory when the transfer occurs. 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.

CECONY

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

New Financial Accounting Standards

New Financial Accounting Standards

In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board jointly issued a revenue recognition standard that will supersede the revenue recognition requirements within Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. Additionally, in March and April 2016, respectively, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations (Reporting Revenue Gross Versus Net)” to clarify how to apply the implementation guidance for principal versus agent considerations and ASU No. 2016-10,“Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing” to clarify the guidance pertaining to identifying performance obligations and licensing implementation guidance. Furthermore in May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” to clarify assessing collectibility, presentation of sales taxes, noncash consideration, contract modification at transition, and completed contracts at transition. The new standard is effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for reporting periods beginning after December 15, 2016. The Companies are in the process of evaluating the application and impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The

Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” This amendment requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments in this Update are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of the 2014-09 and 2014-16. The Companies are in the process of evaluating the potential impact of the amendments on the Companies’ financial position, results of operations and liquidity.

In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial

instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In August 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force).” The amendment specifies the classification and presentation of certain cash flow items to reduce diversity in practice. 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 October 2016, the FASB issued amendments to the guidance for Income Taxes through ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory.” The amendment clarifies the tax treatment of intra-entity transfers of assets other than inventory. The updated guidance requires entities recognize the income tax consequences of an intra-entity transfer of assets other than inventory when the transfer occurs. 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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Acquisitions, Investments and Dispositions

9 Months Ended

Sep. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

Acquisitions, Investments and Dispositions

Acquisitions, Investments and Dispositions

Acquisitions and Investments

Texas Solar 7

In January 2016, Con Edison Development acquired a 100 percent interest in a company that is the owner of a 106 MW (AC) solar electric production project in Texas (Texas Solar 7) for $227 million; $218 million was recorded as non-utility construction work in progress and the remaining $9 million was recorded as other receivables. At September 30, 2016 net assets of the project are approximately $123 million. The project has been financed, in part, by debt secured by the project (see Note C). Electricity generated by this project is to be purchased by the City of San Antonio pursuant to a long-term power purchase agreement. The project commenced commercial operation in the third quarter of 2016. Con Edison's interest in Texas Solar 7 is consolidated in the financial statements.

Mountain Valley Pipeline

In January 2016, CET Gas acquired a 12.5 percent equity interest in Mountain Valley Pipeline, LLC (MVP), a company developing a proposed gas transmission project in West Virginia and Virginia. The company's initial contribution to MVP was $18 million. At September 30, 2016, CET Gas' investment in MVP was $41 million. The estimated total project cost is $3,000 million to $3,500 million. Subject to FERC approval, MVP is targeting to be fully in-service during 2018. Con Edison is accounting for its equity interest in MVP as an equity method investment.

Stagecoach Gas Services

In April 2016, a CET Gas subsidiary agreed with a subsidiary of Crestwood to form a joint venture to own, operate and further develop existing natural gas pipeline and storage businesses located in northern Pennsylvania and southern New York. The transaction was substantially completed during June 2016. Crestwood contributed businesses to a new entity, Stagecoach, and the CET Gas subsidiary purchased a 50 percent equity interest in Stagecoach for $945 million (subject to closing adjustments). At September 30, 2016, CET Gas' investment in Stagecoach was $968 million. Con Edison is accounting for its equity interest in Stagecoach as an equity method investment.

NY Transco

In January 2016, CECONY entered into an agreement to transfer certain electric transmission projects to NY Transco, a company in which CET Electric has a 45.7 percentequity interest. In April 2016, the NYSPSC authorized CECONY, subject to certain conditions, to transfer the projects to NY Transco. In May 2016, CECONY transferred the projects to NY Transco for a purchase price of $122 million and an $8 million payment for easement rights on certain associated property. At September 30, 2016, CET Electric's investment in NY Transco was $53 million. Con Edison is accounting for its equity interest in NY Transco as an equity method investment.

Pilesgrove

In June 2016, Con Edison Development recorded an $8 million ($5 million, net of taxes) impairment charge on its 50 percent interest in Pilesgrove Solar, LLC (Pilesgrove), which owns an 18 MW (AC) solar electric production project in New Jersey. In August 2016, Con Edison Development acquired the remaining 50 percent interest in Pilesgrove for a purchase price of approximately $16 million and recorded a bargain purchase gain of $8 million ($5 million, net of taxes). The impairment charge and bargain purchase gain are included in Investment and other income on Con Edison’s consolidated income statement. Con Edison's interest in Pilesgrove is consolidated in the financial statements subsequent to the August 2016 acquisition. At September 30, 2016, net assets of the project are approximately $48 million, consisting primarily of $45 million recorded as non-utility property and $3 million recorded in current assets.

Panoche Valley

In October 2016, Con Edison Development acquired the remaining 50 percent interest in Panoche Holdings, LLC, which is developing a 240 MW (AC) solar electric production project in California, for cash consideration of $37 million, net of applicable purchase price adjustments. Con Edison will consolidate the project on its financial statements as of the date of acquisition. See Note M.

Dispositions

Pike County Light & Power Company (Pike)

In October 2015, upon evaluating strategic alternatives, O&R entered into an agreement to sell Pike to Corning Natural Gas Holding Corporation (Corning). In August 2016, the sale was completed. O&R received cash consideration of $15 million for the sale. O&R has agreed to provide transition services to Corning for operations and customer support for a period of up to 18 months subsequent to the sale. In addition, O&R will continue to purchase and sell to Pike electric and gas commodity for three years. Pike has an option to extend the service for up to an additional three years.

At September 30, 2015, O&R recorded an impairment charge of $5 million ($3 million, net of taxes), representing the difference between the carrying amount of Pike’s assets and the estimated sales proceeds. At December 31, 2015, Pike’s total assets and liabilities held for sale were $23 million and $5 million, respectively. There were no amounts outstanding at September 30, 2016.

Con Edison Solutions' Retail Electric Supply Business

In July 2016, Con Edison Solutions entered into an agreement to sell the assets of its retail electric supply business (including retail contracts, related derivative instruments, information systems, and accounts receivable) to a subsidiary of Exelon Corporation (Exelon). In September 2016, the sale was completed for cash consideration of $235 million, subject to working capital adjustments. The sale resulted in a gain of $104 million ($47 million, net of taxes), inclusive of a $65 million ($42 million, net of taxes) gain on derivative instruments. The tax effect of the sale includes $29 million ($19 million, net of federal tax) of state taxes related to a change in the apportionment of state income taxes. Con Edison Solutions has agreed to provide transition services to the Exelon subsidiary for operations and customer support through the end of 2017 during which period certain guarantees or other credit support provided by Con Edison in connection with the retail electric supply business may continue in effect. See Note H. At December 31, 2015, Con Edison Solutions' total assets and liabilities held for sale were $134 million and $84 million, respectively. There were no amounts outstanding at September 30, 2016.

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2016

Accounting Policies [Abstract]

New Financial Accounting Standards

New Financial Accounting Standards

In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board jointly issued a revenue recognition standard that will supersede the revenue recognition requirements within Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. Additionally, in March and April 2016, respectively, the FASB issued ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal Versus Agent Considerations (Reporting Revenue Gross Versus Net)” to clarify how to apply the implementation guidance for principal versus agent considerations and ASU No. 2016-10,“Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing” to clarify the guidance pertaining to identifying performance obligations and licensing implementation guidance. Furthermore in May 2016, the FASB issued ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” to clarify assessing collectibility, presentation of sales taxes, noncash consideration, contract modification at transition, and completed contracts at transition. The new standard is effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for reporting periods beginning after December 15, 2016. The Companies are in the process of evaluating the application and impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The

Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” This amendment requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments in this Update are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning after December 15, 2016. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of the 2014-09 and 2014-16. The Companies are in the process of evaluating the potential impact of the amendments on the Companies’ financial position, results of operations and liquidity.

In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial

instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In August 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force).” The amendment specifies the classification and presentation of certain cash flow items to reduce diversity in practice. 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 October 2016, the FASB issued amendments to the guidance for Income Taxes through ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory.” The amendment clarifies the tax treatment of intra-entity transfers of assets other than inventory. The updated guidance requires entities recognize the income tax consequences of an intra-entity transfer of assets other than inventory when the transfer occurs. 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)

9 Months Ended

Sep. 30, 2016

Accounting Policies [Abstract]

Earnings Per Common Share

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

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2016	2015
Net income	$497	$428	$1,039	$1,017
Weighted average common shares outstanding – basic	304.5	292.9	299.1	292.9
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	305.9	294.2	300.5	294.2
Net income per common share – basic	$1.63	$1.46	$3.47	$3.47
Net income per common share – diluted	$1.62	$1.45	$3.46	$3.46

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

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(33)	$(39)	$(8)	$(10)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2016 and 2015 (a)(b)	1	1	—	1
Current period OCI, net of taxes	1	1	—	1
Ending balance, accumulated OCI, net of taxes	$(32)	$(38)	$(8)	$(9)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance, accumulated OCI, net of taxes (a)	$(34)	$(45)	$(9)	$(11)
OCI before reclassifications, net of tax of $1 and $(2) for Con Edison in 2016 and 2015, respectively	(1)	3	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) and $(3) for Con Edison in 2016 and 2015 (a)(b)	3	4	1	2
Current period OCI, net of taxes	2	7	1	2
Ending balance, accumulated OCI, net of taxes	$(32)	$(38)	$(8)	$(9)

(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)

9 Months Ended

Sep. 30, 2016

Regulated Operations [Abstract]

Summary of Rate Plan

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

Effective period	January 2017 - December 2019
Base rate changes (a)	Yr. 1 - $195 million Yr. 2 - $155 million Yr. 3 - $155 million
Amortizations to income of net regulatory (assets) liabilities	Yr. 1 - $84 million Yr. 2 - $83 million Yr. 3 - $69 million
Other revenue sources	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $28 million; Yr. 2 - $47 million; and Yr. 3 - $64 million.
Revenue decoupling mechanism	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $376 million; Yr. 2 - $383 million; and Yr. 3 - $395 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes(b), municipal infrastructure support costs(c), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(d)
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $21,689 million; Yr. 2 - $22,338 million; Yr. 3 - $23,002 million AMI: Yr. 1 - $126 million; Yr. 2 - $257 million; Yr. 3 - $415 million
Average rate base	Yr. 1 - $18,902 million Yr. 2 - $19,530 million Yr. 3 - $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.00 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent

(a) The electric base rate increases shown above are in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the current rate plan. At the NYSPSC’s option, these increases may be implemented with increases of $199 million in each rate year.

(b) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(c) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral of 30 percent of the amount reflected in rates.

(d) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers.

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

Effective period	January 2017 - December 2019
Base rate changes	Yr. 1 - $(5) million(a) Yr. 2 - $92 million Yr. 3 - $90 million
Amortizations to income of net regulatory (assets) liabilities	Yr. 1 - $39 million Yr. 2 - $37 million Yr. 3 - $36 million
Other revenue sources	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 - $7 million; Yr. 2 - $8 million; and Yr. 3 - $8 million.
Revenue decoupling mechanism	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 - $68 million; Yr. 2 - $75 million; and Yr. 3 - $83 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(b)
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $5,844 million; Yr. 2 - $6,512 million; Yr. 3 - $7,177 million AMI: Yr. 1 - $27 million; Yr. 2 - $57 million; Yr. 3 - $100 million
Average rate base	Yr. 1 - $4,841 million Yr. 2 - $5,395 million Yr. 3 - $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.00 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent

(a) The base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the current rate plan.

(b) See footnotes (b), (c) and (d) to the table under “CECONY-Electric,” above.

Regulatory Assets and Liabilities

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$3,369	$3,876	$3,220	$3,697
Future income tax	2,429	2,350	2,312	2,232
Environmental remediation costs	823	904	720	800
Revenue taxes	298	253	283	240
Deferred storm costs	89	185	30	110
Deferred derivative losses	55	50	49	46
Unamortized loss on reacquired debt	45	50	43	48
Surcharge for New York State assessment	43	44	40	40
O&R property tax reconciliation	39	46	—	—
Pension and other postretirement benefits deferrals	34	45	3	16
Net electric deferrals	29	44	29	44
Preferred stock redemption	25	26	25	26
O&R transition bond charges	16	21	—	—
Workers’ compensation	15	11	15	11
Recoverable energy costs	7	16	5	15
Other	228	175	212	157
Regulatory assets – noncurrent	7,544	8,096	6,986	7,482
Deferred derivative losses	94	113	87	103
Recoverable energy costs	25	19	24	18
Regulatory assets – current	119	132	111	121
Total Regulatory Assets	$7,663	$8,228	$7,097	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$713	$676	$602	$570
Property tax reconciliation	205	303	205	303
Pension and other postretirement benefit deferrals	163	76	130	46
Net unbilled revenue deferrals	121	109	121	109
Prudence proceeding	96	99	96	99
Unrecognized other postretirement costs	91	28	91	28
New York State income tax rate change	66	75	64	72
Base rate change deferrals	62	128	62	128
Variable-rate tax-exempt debt – cost rate reconciliation	60	70	52	60
Carrying charges on repair allowance and bonus depreciation	57	49	56	48
Earnings sharing - electric, gas and steam	34	80	26	80
Net utility plant reconciliations	27	32	27	31
Property tax refunds	12	44	12	44
World Trade Center settlement proceeds	5	21	5	21
Other	208	187	176	150
Regulatory liabilities – noncurrent	1,920	1,977	1,725	1,789
Revenue decoupling mechanism	74	45	70	45
Refundable energy costs	37	64	18	33
Deferred derivative gains	12	6	8	6
Regulatory liabilities – current	123	115	96	84
Total Regulatory Liabilities	$2,043	$2,092	$1,821	$1,873

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Capitalization (Tables)

9 Months Ended

Sep. 30, 2016

Debt Disclosure [Abstract]

Carrying Amounts and Fair Values of Long-Term Debt

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

(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,093	$16,325	$12,745	$13,856
CECONY	$11,584	$13,564	$11,437	$12,427

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Pension Benefits (Tables)

9 Months Ended

Sep. 30, 2016

Pension Benefits

Total Periodic Benefit Costs

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$69	$74	$65	$70
Interest cost on projected benefit obligation	149	144	140	135
Expected return on plan assets	(237)	(222)	(225)	(210)
Recognition of net actuarial loss	149	194	141	183
Recognition of prior service costs	1	1	—	—
NET PERIODIC BENEFIT COST	$131	$191	$121	$178
Amortization of regulatory asset	—	1	—	1
TOTAL PERIODIC BENEFIT COST	$131	$192	$121	$179
Cost capitalized	(51)	(80)	(49)	(76)
Reconciliation to rate level	10	(14)	13	(14)
Cost charged to operating expenses	$90	$98	$85	$89

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost – including administrative expenses	$207	$223	$194	$209
Interest cost on projected benefit obligation	447	431	419	404
Expected return on plan assets	(711)	(664)	(674)	(630)
Recognition of net actuarial loss	447	581	424	550
Recognition of prior service costs	3	3	1	1
NET PERIODIC BENEFIT COST	$393	$574	$364	$534
Amortization of regulatory asset	—	2	—	2
TOTAL PERIODIC BENEFIT COST	$393	$576	$364	$536
Cost capitalized	(157)	(224)	(148)	(214)
Reconciliation to rate level	35	(56)	39	(56)
Cost charged to operating expenses	$271	$296	$255	$266

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Other Postretirement Benefits (Tables)

9 Months Ended

Sep. 30, 2016

Other Postretirement Benefits

Defined Benefit Plan Disclosure [Line Items]

Total Periodic Benefit Costs

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

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

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Service cost	$13	$15	$10	$11
Interest cost on accumulated other postretirement benefit obligation	36	38	30	32
Expected return on plan assets	(58)	(59)	(50)	(51)
Recognition of net actuarial loss	4	24	2	21
Recognition of prior service cost	(15)	(15)	(11)	(10)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(20)	$3	$(19)	$3
Cost capitalized	5	(2)	5	(2)
Reconciliation to rate level	20	12	19	5
Cost charged to operating expenses	$5	$13	$5	$6

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Environmental Matters (Tables)

9 Months Ended

Sep. 30, 2016

Environmental Remediation Obligations [Abstract]

Accrued Liabilities and Regulatory Assets

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$664	$679	$574	$579
Other Superfund Sites	88	86	87	86
Total	$752	$765	$661	$665
Regulatory assets	$823	$904	$720	$800

Environmental Remediation Costs

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

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$8	$6	$5	$6

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$20	$21	$10	$18

Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at September 30, 2016 and December 31, 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$90	$86	$85	$81
Regulatory assets – workers’ compensation	$15	$11	$15	$11

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Other Material Contingencies (Tables)

9 Months Ended

Sep. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Total Guarantees

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

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$618	$430		$—	$1,048
Energy transactions	635	57	91		783
Renewable electric production projects	445	—	18		463
Other	128	—	—		128
Total	$1,826	$487	$109		$2,422

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Financial Information by Business Segment (Tables)

9 Months Ended

Sep. 30, 2016

Segment Reporting [Abstract]

Financial Data for Business Segments

The financial data for the business segments are as follows:

	As of and for the Three Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)		Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$2,557	$2,558	$5		$4		$217	$207	$841	$811	$2	$(2)	$117	$111	$275	$260	$30,580	$30,369	$411	$419
Gas	208	213	1		1		41	35	(28)	(17)	—	(1)	27	24	(24)	(17)	7,300	6,687	224	178
Steam	63	58	22		22		20	20	(47)	(49)	—	—	10	10	(17)	(18)	2,556	2,614	24	27
Consolidation adjustments	—	—	(28)		(27)		—	—	—	—	—	—	—	—	—	—	—	—	—	—
Total CECONY	$2,828	$2,829		$—		$—	$278	$262	$766	$745	$2	$(3)	$154	$145	$234	$225	$40,436	$39,670	$659	$624
O&R
Electric	$213	$205		$—		$—	$12	$13	$55	$51	$1	$(4)	$6	$6	$20	$17	$1,985	$1,959	$24	$26
Gas	27	24	—		—		5	4	(7)	(9)	—	(1)	3	3	(4)	(5)	799	754	14	12
Total O&R	$240	$229		$—		$—	$17	$17	$48	$42	$1	$(5)	$9	$9	$16	$12	$2,784	$2,713	$38	$38
Competitive energy businesses	$350	$386	$(2)		$(2)		$11	$6	$125	$43	$27	$17	$7	$2	$67	$21	$2,394	$1,547	$121	$212
Con Edison Transmission	—	—	—		—		—	—	(1)	—	20	—	3	—	—	—	1,072	2	—	—
Other (a)	(1)	(1)	2		2		(1)	—	2	—	(1)	—	5	6	4	2	630	1,039	—	—
Total Con Edison	$3,417	$3,443		$—		$—	$305	$285	$940	$830	$49	$9	$178	$162	$321	$260	$47,316	$44,971	$818	$874

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

	As of and for the Nine Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income		Other income (deductions)		Interest charges		Income taxes on operating income		Total assets		Construction expenditures
(Millions of Dollars)	2016	2015	2016		2015		2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015	2016	2015
CECONY
Electric	$6,222	$6,416	$13		$13		$645	$610	$1,487	$1,511	$3	$(3)	$342	$333	$412	$401	$30,580	$30,369	$1,133	$1,165
Gas	1,113	1,177	4		4		118	105	273	278	(1)	(1)	79	71	73	82	7,300	6,687	589	466
Steam	406	529	65		65		62	58	39	100	—	—	30	31	18	42	2,556	2,614	74	65
Consolidation adjustments	—	—	(82)		(82)		—	—	—	—	—	—	—	—	—	—	—	—	—	—
Total CECONY	$7,741	$8,122		$—		$—	$825	$773	$1,799	$1,889	$2	$(4)	$451	$435	$503	$525	$40,436	$39,670	$1,796	$1,696
O&R
Electric	$497	$523		$—		$—	$37	$38	$86	$85	$1	$(2)	$19	$18	$27	$26	$1,985	$1,959	$70	$72
Gas	133	117	—		—		13	13	28	—	—	(2)	9	9	8	(4)	799	754	36	29
Total O&R	$630	$640		$—		$—	$50	$51	$114	$85	$1	$(4)	$28	$27	$35	$22	$2,784	$2,713	$106	$101
Competitive energy businesses	$998	$1,087	$7		$(5)		$30	$16	$184	$53	$36	$33	$23	$5	$76	$24	$2,394	$1,547	$677	$676
Con Edison Transmission	—	—	—		—		—	—	(1)	—	23	—	4	—	—	—	1,072	2	—	—
Other (a)	(1)	(2)	(7)		5		—	—	1	1	(1)	(2)	11	19	6	3	630	1,039	—	—
Total Con Edison	$9,368	$9,847		$—		$—	$905	$840	$2,097	$2,028	$61	$23	$517	$486	$620	$574	$47,316	$44,971	$2,579	$2,473

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

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Derivative Instruments and Hedging Activities (Tables)

9 Months Ended

Sep. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Values of Commodity Derivatives Including Offsetting Assets

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

(Millions of Dollars)	2016				2015
Balance Sheet Location	Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)		Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)
Con Edison
Fair value of derivative assets
Current	$75	$(60)	$15	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	58	(57)	1		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$133	$(117)	$16		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(143)	$73	$(70)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(111)	59	(52)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(254)	$132	$(122)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(121)	$15	$(106)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(46)	$6	(b)	$40	$(32)	$8	(b)
Noncurrent	45	(45)	—		48	(47)	1
Total fair value of derivative assets	$97	$(91)	$6		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(122)	$61	$(61)		$(121)	$71	$(50)
Noncurrent	(92)	47	(45)		(92)	56	(36)
Total fair value of derivative liabilities	$(214)	$108	$(106)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(117)	$17	$(100)	(b)	$(125)	$48	$(77)	(b)

(a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount.

(b) At September 30, 2016 and December 31, 2015, margin deposits for Con Edison ($12 million and $26 million, respectively) and CECONY ($12 million and $26 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

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

Fair Values of Commodity Derivatives Including Offsetting Liabilities

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

(Millions of Dollars)	2016				2015
Balance Sheet Location	Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)		Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)
Con Edison
Fair value of derivative assets
Current	$75	$(60)	$15	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	58	(57)	1		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$133	$(117)	$16		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(143)	$73	$(70)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(111)	59	(52)		(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(254)	$132	$(122)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(121)	$15	$(106)	(b)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(46)	$6	(b)	$40	$(32)	$8	(b)
Noncurrent	45	(45)	—		48	(47)	1
Total fair value of derivative assets	$97	$(91)	$6		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(122)	$61	$(61)		$(121)	$71	$(50)
Noncurrent	(92)	47	(45)		(92)	56	(36)
Total fair value of derivative liabilities	$(214)	$108	$(106)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(117)	$17	$(100)	(b)	$(125)	$48	$(77)	(b)

(a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount.

(b) At September 30, 2016 and December 31, 2015, margin deposits for Con Edison ($12 million and $26 million, respectively) and CECONY ($12 million and $26 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

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

Realized and Unrealized Gains or Losses on Commodity Derivatives

The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2016 and 2015:

		For the Three Months Ended September 30,
		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(1)		$(1)		$(3)		$(1)
Noncurrent	Deferred derivative gains	(2)		—		—		—
Total deferred gains/(losses)		$(3)		$(1)		$(3)		$(1)
Current	Deferred derivative losses	$(19)		$8		$(18)		$8
Current	Recoverable energy costs	(39)		(53)		(35)		(49)
Noncurrent	Deferred derivative losses	(17)		14		(14)		13
Total deferred gains/(losses)		$(75)		$(31)		$(67)		$(28)
Net deferred gains/(losses)		$(78)		$(32)		$(70)		$(29)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(37)	(a)	$(31)	(b)		$—		$—
	Gas purchased for resale	(38)		(26)		—		—
	Non-utility revenue	(2)	(a)	5	(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(77)		$(52)			$—		$—

(a) For the three months ended September 30, 2016, Con Edison recorded unrealized losses in non-utility operating revenue ($2 million) and purchase power expense ($23 million).

(b) For the three months ended September 30, 2015, Con Edison recorded in purchased power expense an unrealized pre-tax gain of $12 million.

		For the Nine Months Ended September 30,
		Con Edison					CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015			2016		2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$6			$—		$2		$1
Noncurrent	Deferred derivative gains	(1)		—			(1)		—
Total deferred gains/(losses)		$5			$—		$1		$1
Current	Deferred derivative losses	$19		$40			$16		$40
Current	Recoverable energy costs	(163)		(92)			(148)		(87)
Noncurrent	Deferred derivative losses	(5)		(7)			(3)		(5)
Total deferred gains/(losses)		$(149)		$(59)			$(135)		$(52)
Net deferred gains/(losses)		$(144)		$(59)			$(134)		$(51)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(106)	(a)	$(60)		(b)		$—		$—
	Gas purchased for resale	(72)		(94)			—		—
	Non-utility revenue	15	(a)	20		(b)	—		—
Total pre-tax gain/(loss) recognized in income		$(163)		$(134)				$—		$—

(a) For the nine months ended September 30, 2016, Con Edison recorded unrealized gains and losses in non-utility operating revenue ($3 million loss) and purchase power expense ($11 million gain).

(b) For the nine months ended September 30, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($3 million loss) and purchased power expense ($6 million gain).

Hedged Volume of Derivative Transactions

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

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	22,797,395	15,472	69,954,738	1,344,000
CECONY	20,724,225	9,000	70,100,000	1,344,000

(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 September 30, 2016:

(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$111		$97
Collateral posted	24		23
Additional collateral (b) (downgrade one level from current ratings)	18		15
Additional collateral (b) (downgrade to below investment grade from current ratings)	106	(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 competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $10 million at September 30, 2016. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) Derivative instruments that are net assets have been excluded from the table. At September 30, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $9 million.

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2016

Fair Value Disclosures [Abstract]

Assets and Liabilities Measured at Fair Value on Recurring Basis

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

	2016					2015
(Millions of Dollars)	Level 1	Level 2	Level 3	Netting Adjustment (e)	Total	Level 1	Level 2	Level 3		Netting Adjustment (e)	Total
Con Edison
Derivative assets:
Commodity (a)(b)(c)	$6	$21	$6	$(5)	$28	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	—	—	—	—	—	63	1		(63)	1
Other (a)(b)(d)	224	113	—	—	337	185	112	—		—	297
Total assets	$230	$134	$6	$(5)	$365	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$3	$146	$5	$(32)	$122	$16	$153	$1		$(65)	$105
Commodity held for sale (f)	—	—	—	—	—	1	133	7		(63)	78
Total liabilities	$3	$146	$5	$(32)	$122	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$4	$7	$1	$6	$18	$1	$9	$8		$17	$35
Other (a)(b)(d)	200	108	—	—	308	171	105	—		—	276
Total assets	$204	$115	$1	$6	$326	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$2	$126	$1	$(23)	$106	$14	$129		$—	$(57)	$86

(a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. There were no transfers between levels 1, 2 and 3 for the nine months ended September 30, 2016 and for the year ended December 31, 2015.

(b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.

(c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2016 and December 31, 2015, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.

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

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

(f) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet.

Schedule of Commodity Derivatives

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

	Fair Value of Level 3 at September 30, 2016		Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
Con Edison – Commodity
Electricity	$(1)		Discounted Cash Flow	Forward energy prices (a)	$19.75-$80.00 per MWh
	1		Discounted Cash Flow	Forward capacity prices (a)	$2.68-$9.45 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)	52.8%-59.4%
				Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(44.9)%-58.9%
				Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(0.14)-$2.82 per MWh
Total Con Edison—Commodity	$1
CECONY—Commodity
Electricity	$(1)		Discounted Cash Flow	Forward energy prices (a)	$21.10-$80.00 per MWh
Transmission Congestion Contracts	$1		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	52.8%-59.4%
				Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(44.9)%-58.9%
Total CECONY—Commodity		$—

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

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

Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of September 30, 2016 and 2015 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016		2015
Beginning balance as of July 1,	$5	$13	$2		$11
Included in earnings	(4)	(4)	—		(1)
Included in regulatory assets and liabilities	(5)	(1)	(3)		(1)
Purchases	—	1	—		1
Sales (a)	4	—	—		—
Settlements	1	(5)	1		(2)
Ending balance as of September 30,	$1	$4		$—	$8

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016		2015
Beginning balance as of January 1,	$6	$20	$8		$13
Included in earnings	(1)	(18)	(1)		(5)
Included in regulatory assets and liabilities	(11)	(1)	(6)		(1)
Purchases	2	9	1		5
Sales (a)	4	—	—		—
Settlements	1	(6)	(2)		(4)
Ending balance as of September 30,	$1	$4		$—	$8

(a) Amounts represent derivative instruments novated as part of the assets of Con Edison Solutions’ retail electric supply business which were sold to a subsidiary of Exelon Corporation (see Note P).

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Variable Interest Entities (Tables)

9 Months Ended

Sep. 30, 2016

Equity Method Investments and Joint Ventures [Abstract]

Summary of VIEs

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

Project Name (a)	Generating Capacity (b) (MW AC)	Power Purchase Agreement Term (in Years)	Year of Initial Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (c)
Copper Mountain Solar 3	128	20	2014	Nevada	$179
Panoche Valley (d)	120	20	2015	California	274
Mesquite Solar 1	83	20	2013	Arizona	107
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	70
Broken Bow II	38	25	2014	Nebraska	51
Texas Solar 4	32	25	2014	Texas	43

(a) With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development. The maximum exposure for Texas Solar 4 is the net assets of the investment offset by an $8 million noncontrolling interest.

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

(c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet and any related receivables due from the project. For consolidated investments, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

(d) In October 2016, Con Edison Development acquired the remaining 50 percent ownership interest in the project. See Note P.

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General (Details)	9 Months Ended
	Sep. 30, 2016 subsidiary registrant
Accounting Policies [Abstract]
Number of registrants | registrant	2
Number of regulated utility subsidiaries | subsidiary	2

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Summary of Significant Accounting Policies - Earnings Per Common Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2016	Sep. 30, 2015
Accounting Policies [Abstract]
Net income	$ 497	$ 232	$ 310	$ 428	$ 219	$ 370	$ 1,039	$ 1,017
Weighted average common shares outstanding – basic	304.5			292.9			299.1	292.9
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	305.9			294.2			300.5	294.2
Net income per common share-basic (dollars per share)	$ 1.63			$ 1.46			$ 3.47	$ 3.47
Net income per common share-diluted (dollars per share)	$ 1.62			$ 1.45			$ 3.46	$ 3.46

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Summary of Significant Accounting Policies - Changes in Accumulated Other Comprehensive Income/(Loss) by Component (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	$ 13,958	$ 12,797	$ 13,061	$ 12,585
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	2	7
Ending Balance	14,275	13,049	14,275	13,049
OCI before reclassifications, tax			1	(2)
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(1)	(1)	(2)	(3)
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	0	1	1	2
Accumulated Other Comprehensive Income/(Loss)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(33)	(39)	(34)	(45)
OCI before reclassifications, net of tax			(1)	3
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	1	1	3	4
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	1	2	7
Ending Balance	(32)	(38)	(32)	(38)
Accumulated Other Comprehensive Income/(Loss) | CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(8)	(10)	(9)	(11)
OCI before reclassifications, net of tax			0	0
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	0	1	1	2
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	0	1	1	2
Ending Balance	$ (8)	$ (9)	$ (8)	$ (9)

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Regulatory Matters - Summary of Rate Plan (Detail) - USD ($) $ in Millions	1 Months Ended		9 Months Ended	36 Months Ended
	Oct. 31, 2016	Apr. 30, 2016	Sep. 30, 2016	Dec. 31, 2019
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Additional rate increase			$ 48
Deferrals for property taxes limitation from rates (percent)			90.00%
Deferrals for property taxes limitation from rates (percent)			80.00%
Maximum deferral (percentage)			30.00%
CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Additional rate increase			$ 41
New Jersey Board of Public Utilities | Rockland Electric Company | Year 1 | Rockland Electric Company | Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount		$ 10
Return on common equity (percent)		10.20%
Common equity ratio (percent)		49.81%
Scenario, Forecast | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Public utilities, term of rate plan				3 years
Authorized return on common equity (percent)				9.00%
Earnings sharing (percentage)				9.50%
Common equity ratio (percent)				48.00%
Scenario, Forecast | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Public utilities, term of rate plan				3 years
Retention of revenues from non-firm customers (up to)				$ 65
Percentage of revenue reserve				15.00%
Authorized return on common equity (percent)				9.00%
Earnings sharing (percentage)				9.50%
Common equity ratio (percent)				48.00%
Scenario, Forecast | Year 1 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ 195
Amortization to income of net regulatory (assets) and liabilities				84
Retention of annual transmission congestion revenues				75
Potential incentive revenue				28
Potential penalty expense				376
Average rate base				$ 18,902
Weighted average cost of capital (after-tax) (percent)				6.82%
Cost of long-term debt (percent)				4.93%
Additional rate increase				$ 199
Deferral, annual maximum (not more than) (percent)				0.10%
Scenario, Forecast | Year 1 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ (5)
Amortization to income of net regulatory (assets) and liabilities				39
Potential incentive revenue				7
Potential penalty expense				68
Average rate base				$ 4,841
Weighted average cost of capital (after-tax) (percent)				6.82%
Cost of long-term debt (percent)				4.93%
Scenario, Forecast | Year 2 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ 155
Amortization to income of net regulatory (assets) and liabilities				83
Retention of annual transmission congestion revenues				75
Potential incentive revenue				47
Potential penalty expense				383
Average rate base				$ 19,530
Weighted average cost of capital (after-tax) (percent)				6.80%
Cost of long-term debt (percent)				4.88%
Additional rate increase				$ 199
Deferral, annual maximum (not more than) (percent)				0.075%
Scenario, Forecast | Year 2 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ 92
Amortization to income of net regulatory (assets) and liabilities				37
Potential incentive revenue				8
Potential penalty expense				75
Average rate base				$ 5,395
Weighted average cost of capital (after-tax) (percent)				6.80%
Cost of long-term debt (percent)				4.88%
Scenario, Forecast | Year 3 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ 155
Amortization to income of net regulatory (assets) and liabilities				69
Retention of annual transmission congestion revenues				75
Potential incentive revenue				64
Potential penalty expense				395
Average rate base				$ 20,277
Weighted average cost of capital (after-tax) (percent)				6.73%
Cost of long-term debt (percent)				4.74%
Additional rate increase				$ 199
Deferral, annual maximum (not more than) (percent)				0.05%
Scenario, Forecast | Year 3 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ 90
Amortization to income of net regulatory (assets) and liabilities				36
Potential incentive revenue				8
Potential penalty expense				83
Average rate base				$ 6,005
Weighted average cost of capital (after-tax) (percent)				6.73%
Cost of long-term debt (percent)				4.74%
Net plant target, excluding AMI | Scenario, Forecast | Year 1 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				$ 21,689
Net plant target, excluding AMI | Scenario, Forecast | Year 1 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				5,844
Net plant target, excluding AMI | Scenario, Forecast | Year 2 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				22,338
Net plant target, excluding AMI | Scenario, Forecast | Year 2 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				6,512
Net plant target, excluding AMI | Scenario, Forecast | Year 3 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				23,002
Net plant target, excluding AMI | Scenario, Forecast | Year 3 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				7,177
AMI | Scenario, Forecast | Year 1 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				126
AMI | Scenario, Forecast | Year 1 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				27
AMI | Scenario, Forecast | Year 2 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				257
AMI | Scenario, Forecast | Year 2 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				57
AMI | Scenario, Forecast | Year 3 | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				415
AMI | Scenario, Forecast | Year 3 | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Average net utility plant rates				$ 100
Subsequent Event | New Jersey Board of Public Utilities | Rockland Electric Company | Year 1 | Rockland Electric Company | Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate amount	$ (4)
Return on common equity (percent)	10.20%
Common equity ratio (percent)	50.15%
Subsequent Event | New Jersey Board of Public Utilities | Rockland Electric Company | Year 2 | Rockland Electric Company | Electric
Public Utilities, General Disclosures [Line Items]
Public utilities, requested rate increase (decrease), amount	$ 6

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Regulatory Matters - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Sep. 30, 2016
Public Utilities, General Disclosures [Line Items]
Expected credit to customers				$ 116,000,000
Return on capital expenditures, not recoverable (up to)				55,000,000
Regulatory liabilities		$ 1,977,000,000		1,920,000,000
Prudence proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities		99,000,000		96,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities		1,789,000,000		1,725,000,000
Requested deferral of incremental costs incurred to regulatory asset		35,000,000	$ 29,000,000
CECONY | Prudence proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities		$ 99,000,000		96,000,000
CECONY | June 2014 Plastic Fusion Proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities				$ 28,000,000
Scenario, Forecast | CECONY
Public Utilities, General Disclosures [Line Items]
Requested deferral of incremental costs incurred to regulatory asset	$ 37,000,000

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Regulatory Matters - Regulatory Assets and Liabilities (Detail) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Regulatory assets
Regulatory assets – noncurrent	$ 7,544	$ 8,096
Regulatory assets – current	119	132
Total Regulatory Assets	7,663	8,228
Regulatory liabilities
Regulatory liabilities – noncurrent	1,920	1,977
Regulatory liabilities – current	123	115
Total Regulatory Liabilities	2,043	2,092
Allowance for cost of removal less salvage
Regulatory liabilities
Regulatory liabilities – noncurrent	713	676
Property tax reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	205	303
Pension and other postretirement benefit deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	163	76
Net unbilled revenue deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	121	109
Prudence proceeding
Regulatory liabilities
Regulatory liabilities – noncurrent	96	99
Unrecognized other postretirement costs
Regulatory liabilities
Regulatory liabilities – noncurrent	91	28
New York State income tax rate change
Regulatory liabilities
Regulatory liabilities – noncurrent	66	75
Base rate change deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	62	128
Variable-rate tax-exempt debt – cost rate reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	60	70
Carrying charges on repair allowance and bonus depreciation
Regulatory liabilities
Regulatory liabilities – noncurrent	57	49
Earnings sharing - electric, gas and steam
Regulatory liabilities
Regulatory liabilities – noncurrent	34	80
Net utility plant reconciliations
Regulatory liabilities
Regulatory liabilities – noncurrent	27	32
Property tax refunds
Regulatory liabilities
Regulatory liabilities – noncurrent	12	44
World Trade Center settlement proceeds
Regulatory liabilities
Regulatory liabilities – noncurrent	5	21
Other
Regulatory liabilities
Regulatory liabilities – noncurrent	208	187
Revenue decoupling mechanism
Regulatory liabilities
Regulatory liabilities – current	74	45
Refundable energy costs
Regulatory liabilities
Regulatory liabilities – current	37	64
Deferred derivative gains
Regulatory liabilities
Regulatory liabilities – current	12	6
Unrecognized pension and other postretirement costs
Regulatory assets
Regulatory assets – noncurrent	3,369	3,876
Future income tax
Regulatory assets
Regulatory assets – noncurrent	2,429	2,350
Revenue taxes
Regulatory assets
Regulatory assets – noncurrent	298	253
Deferred storm costs
Regulatory assets
Regulatory assets – noncurrent	89	185
Deferred derivative losses
Regulatory assets
Regulatory assets – noncurrent	55	50
Unamortized loss on reacquired debt
Regulatory assets
Regulatory assets – noncurrent	45	50
Surcharge for New York State assessment
Regulatory assets
Regulatory assets – noncurrent	43	44
O&R property tax reconciliation
Regulatory assets
Regulatory assets – noncurrent	39	46
Pension and other postretirement benefits deferrals
Regulatory assets
Regulatory assets – noncurrent	34	45
Net electric deferrals
Regulatory assets
Regulatory assets – noncurrent	29	44
Preferred stock redemption
Regulatory assets
Regulatory assets – noncurrent	25	26
O&R transition bond charges
Regulatory assets
Regulatory assets – noncurrent	16	21
Recoverable energy costs
Regulatory assets
Regulatory assets – noncurrent	7	16
Regulatory assets – current	25	19
Other
Regulatory assets
Regulatory assets – noncurrent	228	175
Deferred derivative losses
Regulatory assets
Regulatory assets – current	94	113
CECONY
Regulatory assets
Regulatory assets – noncurrent	6,986	7,482
Regulatory assets – current	111	121
Total Regulatory Assets	7,097	7,603
Regulatory liabilities
Regulatory liabilities – noncurrent	1,725	1,789
Regulatory liabilities – current	96	84
Total Regulatory Liabilities	1,821	1,873
CECONY | Allowance for cost of removal less salvage
Regulatory liabilities
Regulatory liabilities – noncurrent	602	570
CECONY | Property tax reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	205	303
CECONY | Pension and other postretirement benefit deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	130	46
CECONY | Net unbilled revenue deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	121	109
CECONY | Prudence proceeding
Regulatory liabilities
Regulatory liabilities – noncurrent	96	99
CECONY | Unrecognized other postretirement costs
Regulatory liabilities
Regulatory liabilities – noncurrent	91	28
CECONY | New York State income tax rate change
Regulatory liabilities
Regulatory liabilities – noncurrent	64	72
CECONY | Base rate change deferrals
Regulatory liabilities
Regulatory liabilities – noncurrent	62	128
CECONY | Variable-rate tax-exempt debt – cost rate reconciliation
Regulatory liabilities
Regulatory liabilities – noncurrent	52	60
CECONY | Carrying charges on repair allowance and bonus depreciation
Regulatory liabilities
Regulatory liabilities – noncurrent	56	48
CECONY | Earnings sharing - electric, gas and steam
Regulatory liabilities
Regulatory liabilities – noncurrent	26	80
CECONY | Net utility plant reconciliations
Regulatory liabilities
Regulatory liabilities – noncurrent	27	31
CECONY | Property tax refunds
Regulatory liabilities
Regulatory liabilities – noncurrent	12	44
CECONY | World Trade Center settlement proceeds
Regulatory liabilities
Regulatory liabilities – noncurrent	5	21
CECONY | Other
Regulatory liabilities
Regulatory liabilities – noncurrent	176	150
CECONY | Revenue decoupling mechanism
Regulatory liabilities
Regulatory liabilities – current	70	45
CECONY | Refundable energy costs
Regulatory liabilities
Regulatory liabilities – current	18	33
CECONY | Deferred derivative gains
Regulatory liabilities
Regulatory liabilities – current	8	6
CECONY | Unrecognized pension and other postretirement costs
Regulatory assets
Regulatory assets – noncurrent	3,220	3,697
CECONY | Future income tax
Regulatory assets
Regulatory assets – noncurrent	2,312	2,232
CECONY | Revenue taxes
Regulatory assets
Regulatory assets – noncurrent	283	240
CECONY | Deferred storm costs
Regulatory assets
Regulatory assets – noncurrent	30	110
CECONY | Deferred derivative losses
Regulatory assets
Regulatory assets – noncurrent	49	46
CECONY | Unamortized loss on reacquired debt
Regulatory assets
Regulatory assets – noncurrent	43	48
CECONY | Surcharge for New York State assessment
Regulatory assets
Regulatory assets – noncurrent	40	40
CECONY | O&R property tax reconciliation
Regulatory assets
Regulatory assets – noncurrent	0	0
CECONY | Pension and other postretirement benefits deferrals
Regulatory assets
Regulatory assets – noncurrent	3	16
CECONY | Net electric deferrals
Regulatory assets
Regulatory assets – noncurrent	29	44
CECONY | Preferred stock redemption
Regulatory assets
Regulatory assets – noncurrent	25	26
CECONY | O&R transition bond charges
Regulatory assets
Regulatory assets – noncurrent	0	0
CECONY | Recoverable energy costs
Regulatory assets
Regulatory assets – noncurrent	5	15
Regulatory assets – current	24	18
CECONY | Other
Regulatory assets
Regulatory assets – noncurrent	212	157
CECONY | Deferred derivative losses
Regulatory assets
Regulatory assets – current	87	103
Superfund Sites
Regulatory assets
Total Regulatory Assets	823	904
Superfund Sites | Environmental remediation costs
Regulatory assets
Regulatory assets – noncurrent	823	904
Superfund Sites | CECONY
Regulatory assets
Total Regulatory Assets	720	800
Superfund Sites | CECONY | Environmental remediation costs
Regulatory assets
Regulatory assets – noncurrent	720	800
Workers’ compensation
Regulatory assets
Total Regulatory Assets	15	11
Workers’ compensation | Workers’ compensation
Regulatory assets
Regulatory assets – noncurrent	15	11
Workers’ compensation | CECONY
Regulatory assets
Total Regulatory Assets	15	11
Workers’ compensation | CECONY | Workers’ compensation
Regulatory assets
Regulatory assets – noncurrent	$ 15	$ 11

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Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Detail) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Carrying Amount	$ 14,093	$ 12,745
Fair Value	16,325	13,856
CECONY
Debt Instrument [Line Items]
Carrying Amount	11,584	11,437
Fair Value	$ 13,564	$ 12,427

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Capitalization - Additional Information (Detail) - USD ($)	1 Months Ended				3 Months Ended	9 Months Ended
	Oct. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	May 31, 2016	Jun. 30, 2016	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2016	Feb. 29, 2016	Dec. 31, 2015
Schedule of Capitalization [Line Items]
Stock issued during the period, value					$ 702,000,000
Proceeds from long-term debt						$ 1,765,000,000	$ 238,000,000
Long-term debt, fair value		$ 16,325,000,000				16,325,000,000				$ 13,856,000,000
Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value		15,689,000,000				15,689,000,000
Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value		636,000,000				636,000,000
CECONY
Schedule of Capitalization [Line Items]
Proceeds from long-term debt						550,000,000	$ 0
Long-term debt, fair value		13,564,000,000				13,564,000,000				$ 12,427,000,000
CECONY | Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value		12,928,000,000				12,928,000,000
CECONY | Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value		$ 636,000,000				636,000,000
Tax-exempt debt						$ 636,000,000
Senior Notes | 4.21% Senior Notes due 2041 | Con Edison Development
Schedule of Capitalization [Line Items]
Debt Instrument, face amount									$ 218,000,000
Debt instrument, interest rate (percent)									4.21%
Senior Notes | 4.07% Senior Notes due 2036 | Con Edison Development
Schedule of Capitalization [Line Items]
Debt Instrument, face amount				$ 95,000,000
Debt instrument, interest rate (percent)				4.07%
Secured Debt | 2.00% Debentures due 2021
Schedule of Capitalization [Line Items]
Debt Instrument, face amount				$ 500,000,000
Debt instrument, interest rate (percent)				2.00%
Secured Debt | 3.85% Debentures due 2046 | CECONY
Schedule of Capitalization [Line Items]
Debt Instrument, face amount			$ 550,000,000		$ 550,000,000
Debt instrument, interest rate (percent)			3.85%		3.85%
Secured Debt | New Jersey Utility Agreement | Con Edison Solutions
Schedule of Capitalization [Line Items]
Debt instrument, interest rate (percent)			11.18%		11.18%
Proceeds from long-term debt			$ 2,000,000
Secured Debt | 5.50% Debentures due 2016 | CECONY
Schedule of Capitalization [Line Items]
Debt instrument, interest rate (percent)		5.50%				5.50%
Redemption of debt		$ 400,000,000
Unsecured Debt | Term Loan Credit Facility
Schedule of Capitalization [Line Items]
Debt Instrument, face amount			$ 400,000,000		$ 400,000,000
Common Stock
Schedule of Capitalization [Line Items]
Stock issued during period (in shares)				10,000,000	10,000,000
Stock issued during the period, value				$ 702,000,000	$ 1,000,000
LIBOR | Senior Notes | 4.07% Senior Notes due 2036 | Con Edison Development
Schedule of Capitalization [Line Items]
Debt instrument, basis spread on variable rate (percent)			1.00%
Scenario, Forecast | Secured Debt | 3.88% Debentures due 2016 | O&R
Schedule of Capitalization [Line Items]
Debt Instrument, face amount								$ 75,000,000
Debt instrument, interest rate (percent)								3.88%
Subsequent Event | Secured Debt | 5.45% Debentures due 2016 | O&R
Schedule of Capitalization [Line Items]
Debt instrument, interest rate (percent)	5.45%
Redemption of debt	$ 75,000,000

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Short-Term Borrowing - Additional Information (Detail) - USD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 601,000,000	$ 1,529,000,000
Weighted average interest rate (percent)	0.70%	0.70%
Loans outstanding under credit agreement	$ 0	$ 0
Letters of credit outstanding under the Credit Agreement	2,000,000	15,000,000
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 480,000,000	$ 1,033,000,000
Weighted average interest rate (percent)	0.70%	0.70%
Loans outstanding under credit agreement	$ 0	$ 0
Letters of credit outstanding under the Credit Agreement	$ 2,000,000

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Pension Benefits - Total Periodic Benefit Costs (Detail) - Pension Benefits - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 69	$ 74	$ 207	$ 223
Interest cost on projected benefit obligation	149	144	447	431
Expected return on plan assets	(237)	(222)	(711)	(664)
Recognition of net actuarial loss	149	194	447	581
Recognition of prior service costs	1	1	3	3
NET PERIODIC BENEFIT COST	131	191	393	574
Amortization of regulatory asset	0	1	0	2
TOTAL PERIODIC BENEFIT COST	131	192	393	576
Cost capitalized	(51)	(80)	(157)	(224)
Reconciliation to rate level	10	(14)	35	(56)
Cost charged to operating expenses	90	98	271	296
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	65	70	194	209
Interest cost on projected benefit obligation	140	135	419	404
Expected return on plan assets	(225)	(210)	(674)	(630)
Recognition of net actuarial loss	141	183	424	550
Recognition of prior service costs	0	0	1	1
NET PERIODIC BENEFIT COST	121	178	364	534
Amortization of regulatory asset	0	1	0	2
TOTAL PERIODIC BENEFIT COST	121	179	364	536
Cost capitalized	(49)	(76)	(148)	(214)
Reconciliation to rate level	13	(14)	39	(56)
Cost charged to operating expenses	$ 85	$ 89	$ 255	$ 266

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Pension Benefits - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2016 USD ($)
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 508
Contributions	504
CECONY | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	469
Contributions	466
CECONY | Non-qualified Supplemental Plan
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 17

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Other Postretirement Benefits - Total Periodic Postretirement Benefit Costs (Detail) - Other Postretirement Benefits - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 4	$ 5	$ 13	$ 15
Interest cost on accumulated other postretirement benefit obligation	12	13	36	38
Expected return on plan assets	(19)	(20)	(58)	(59)
Recognition of net actuarial loss	1	8	4	24
Recognition of prior service cost	(5)	(5)	(15)	(15)
NET PERIODIC BENEFIT COST	(7)	1	(20)	3
Cost capitalized	2	(1)	5	(2)
Reconciliation to rate level	7	4	20	12
Cost charged to operating expenses	2	4	5	13
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	4	10	11
Interest cost on accumulated other postretirement benefit obligation	10	11	30	32
Expected return on plan assets	(17)	(17)	(50)	(51)
Recognition of net actuarial loss	1	7	2	21
Recognition of prior service cost	(3)	(4)	(11)	(10)
NET PERIODIC BENEFIT COST	(6)	1	(19)	3
Cost capitalized	2	(1)	5	(2)
Reconciliation to rate level	6	2	19	5
Cost charged to operating expenses	$ 2	$ 2	$ 5	$ 6

XML

Other Postretirement Benefits - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2016 USD ($)
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Expected contributions	$ 6

XML

Environmental Matters - Accrued Liabilities and Regulatory Assets (Detail) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Accrued Liabilities:
Accrued Liabilities	$ 752	$ 765
Regulatory assets	7,663	8,228
Manufactured gas plant sites
Accrued Liabilities:
Accrued Liabilities	664	679
Other Superfund Sites
Accrued Liabilities:
Accrued Liabilities	88	86
Superfund Sites
Accrued Liabilities:
Accrued Liabilities	752	765
Regulatory assets	823	904
CECONY
Accrued Liabilities:
Accrued Liabilities	661	665
Regulatory assets	7,097	7,603
CECONY | Manufactured gas plant sites
Accrued Liabilities:
Accrued Liabilities	574	579
CECONY | Other Superfund Sites
Accrued Liabilities:
Accrued Liabilities	87	86
CECONY | Superfund Sites
Accrued Liabilities:
Accrued Liabilities	661	665
Regulatory assets	$ 720	$ 800

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Environmental Matters - Environmental Remediation Costs (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 8	$ 6	$ 20	$ 21
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 5	$ 6	$ 10	$ 18

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Environmental Matters - Additional Information (Detail) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Site Contingency [Line Items]
Insurance recoveries	$ 1,000,000	$ 0	$ 1,000,000	$ 0
Manufactured gas plant sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)					$ 2,800,000,000
CECONY
Site Contingency [Line Items]
Insurance recoveries	$ 1,000,000	$ 0	$ 1,000,000	$ 0
CECONY | Manufactured gas plant sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)					$ 2,700,000,000
Asbestos Related
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)			15 years
Asbestos Related | CECONY
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)			15 years

XML

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Detail) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Site Contingency [Line Items]
Regulatory assets	$ 7,663	$ 8,228
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers’ compensation
Site Contingency [Line Items]
Accrued liability	90	86
Regulatory assets	15	11
CECONY
Site Contingency [Line Items]
Regulatory assets	7,097	7,603
CECONY | Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY | Workers’ compensation
Site Contingency [Line Items]
Accrued liability	85	81
Regulatory assets	$ 15	$ 11

XML

Other Material Contingencies - Additional Information (Detail)		1 Months Ended	9 Months Ended
	Mar. 12, 2014 building Person	Jul. 31, 2007 Person	Sep. 30, 2016 USD ($) lawsuit	Dec. 31, 2015 USD ($)	Dec. 31, 2014
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 2,422,000,000	$ 2,856,000,000
Ownership interest, percentage					45.70%
Estimated project cost percentage			175.00%
Manhattan Steam Main Rupture
Guarantor Obligations [Line Items]
Number of person died in steam ruptured | Person		1
Number of suits pending against the company | lawsuit			60
Estimated accrued liability for suits			$ 30,000,000
Insurance receivable			$ 39,000,000
Manhattan Explosion and Fire
Guarantor Obligations [Line Items]
Number of suits pending against the company | lawsuit			70
Number of buildings destroyed by fire | building	2
Number of people died in explosion and fire incident | Person	8
Number of people injured in explosion and fire incident | Person	50
Financial And Performance Guarantee For CET Gas
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 25,000,000
Financial And Performance Guarantee During Period in which Con Edison Solutions Provides Transition Services
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			123,000,000
Financial and Performance Guarantee, Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			128,000,000
Indemnity agreements amount			70,000,000
Electric provider obligation to Public Utility Commission of Texas			5,000,000
Finance and Performance Guarantee for Consolidated Edison Solutions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 53,000,000

XML

Other Material Contingencies - Total Guarantees (Detail) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,422	$ 2,856
Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	1,048
Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	783
Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	463
Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	128
0-3 years
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	1,826
0-3 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	618
0-3 years | Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	635
0-3 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	445
0-3 years | Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	128
4-10 years
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	487
4-10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	430
4-10 years | Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	57
4-10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	0
4-10 years | Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	0
Greater than 10 years
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	109
Greater than 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	0
Greater than 10 years | Energy transactions
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	91
Greater than 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	18
Greater than 10 years | Other
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 0

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Income Tax - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Oct. 31, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Income Taxes Disclosure [Line Items]
Income taxes on operating income		$ 314	$ 249	$ 602	$ 548
Effective tax rate		39.00%	37.00%	37.00%	35.00%
Estimated liability for uncertain tax positions		$ 37		$ 37
Uncertain tax positions, reasonably possible to resolve within twelve months		29		29
Uncertain tax positions, reasonably possible to resolve within twelve months, net of federal taxes		20		20
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate		37		37
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate, net of federal taxes		25		25
CECONY
Income Taxes Disclosure [Line Items]
Income taxes on operating income		$ 226	$ 222	$ 491	$ 515
Effective tax rate		37.00%	37.00%	36.00%	35.00%
Estimated liability for uncertain tax positions		$ 5		$ 5
Uncertain tax positions, reasonably possible to resolve within twelve months		5		5
Uncertain tax positions, reasonably possible to resolve within twelve months, net of federal taxes		4		4
Subsequent Event
Income Taxes Disclosure [Line Items]
Income tax refund received	$ 19
Tax Year 2015 | Subsequent Event
Income Taxes Disclosure [Line Items]
Income taxes refund	$ 16
Tax Year 2016
Income Taxes Disclosure [Line Items]
Income taxes refund		$ 32		$ 32

XML

Financial Information by Business Segment - Financial Data for Business Segments (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Operating revenues	$ 3,417	$ 3,443	$ 9,368	$ 9,847
Depreciation and amortization	305	285	905	840
Operating income	940	830	2,097	2,028
Other income (deductions)	49	9	61	23
Interest charges	178	162	517	486
Income taxes on operating income	321	260	620	574
Total assets	47,316	44,971	47,316	44,971	$ 45,642
Construction expenditures	818	874	2,579	2,473
CECONY
Segment Reporting Information [Line Items]
Operating revenues	2,828	2,829	7,741	8,122
Depreciation and amortization	278	262	825	773
Operating income	766	745	1,799	1,889
Other income (deductions)	2	(3)	2	(4)
Interest charges	154	145	451	435
Income taxes on operating income	234	225	503	525
Total assets	40,436	39,670	40,436	39,670	$ 40,230
Construction expenditures	659	624	1,796	1,696
CECONY | Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	217	207	645	610
Operating income	841	811	1,487	1,511
Other income (deductions)	2	(2)	3	(3)
Interest charges	117	111	342	333
Income taxes on operating income	275	260	412	401
Total assets	30,580	30,369	30,580	30,369
Construction expenditures	411	419	1,133	1,165
CECONY | Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	41	35	118	105
Operating income	(28)	(17)	273	278
Other income (deductions)	0	(1)	(1)	(1)
Interest charges	27	24	79	71
Income taxes on operating income	(24)	(17)	73	82
Total assets	7,300	6,687	7,300	6,687
Construction expenditures	224	178	589	466
CECONY | Steam
Segment Reporting Information [Line Items]
Depreciation and amortization	20	20	62	58
Operating income	(47)	(49)	39	100
Other income (deductions)	0	0	0	0
Interest charges	10	10	30	31
Income taxes on operating income	(17)	(18)	18	42
Total assets	2,556	2,614	2,556	2,614
Construction expenditures	24	27	74	65
O&R
Segment Reporting Information [Line Items]
Depreciation and amortization	17	17	50	51
Operating income	48	42	114	85
Other income (deductions)	1	(5)	1	(4)
Interest charges	9	9	28	27
Income taxes on operating income	16	12	35	22
Total assets	2,784	2,713	2,784	2,713
Construction expenditures	38	38	106	101
O&R | Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	12	13	37	38
Operating income	55	51	86	85
Other income (deductions)	1	(4)	1	(2)
Interest charges	6	6	19	18
Income taxes on operating income	20	17	27	26
Total assets	1,985	1,959	1,985	1,959
Construction expenditures	24	26	70	72
O&R | Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	5	4	13	13
Operating income	(7)	(9)	28	0
Other income (deductions)	0	(1)	0	(2)
Interest charges	3	3	9	9
Income taxes on operating income	(4)	(5)	8	(4)
Total assets	799	754	799	754
Construction expenditures	14	12	36	29
Competitive energy businesses
Segment Reporting Information [Line Items]
Depreciation and amortization	11	6	30	16
Operating income	125	43	184	53
Other income (deductions)	27	17	36	33
Interest charges	7	2	23	5
Income taxes on operating income	67	21	76	24
Total assets	2,394	1,547	2,394	1,547
Construction expenditures	121	212	677	676
Con Edison Transmission
Segment Reporting Information [Line Items]
Operating income	(1)	0	(1)	0
Other income (deductions)	20	0	23	0
Interest charges	3	0	4	0
Income taxes on operating income	0	0	0	0
Total assets	1,072	2	1,072	2
Construction expenditures	0	0	0	0
Other
Segment Reporting Information [Line Items]
Depreciation and amortization	(1)	0	0	0
Operating income	2	0	1	1
Other income (deductions)	(1)	0	(1)	(2)
Interest charges	5	6	11	19
Income taxes on operating income	4	2	6	3
Total assets	630	1,039	630	1,039
Construction expenditures	0	0	0	0
Operating revenues
Segment Reporting Information [Line Items]
Operating revenues	3,417	3,443	9,368	9,847
Operating revenues | CECONY
Segment Reporting Information [Line Items]
Operating revenues	2,828	2,829	7,741	8,122
Operating revenues | CECONY | Electric
Segment Reporting Information [Line Items]
Operating revenues	2,557	2,558	6,222	6,416
Operating revenues | CECONY | Gas
Segment Reporting Information [Line Items]
Operating revenues	208	213	1,113	1,177
Operating revenues | CECONY | Steam
Segment Reporting Information [Line Items]
Operating revenues	63	58	406	529
Operating revenues | O&R
Segment Reporting Information [Line Items]
Operating revenues	240	229	630	640
Operating revenues | O&R | Electric
Segment Reporting Information [Line Items]
Operating revenues	213	205	497	523
Operating revenues | O&R | Gas
Segment Reporting Information [Line Items]
Operating revenues	27	24	133	117
Operating revenues | Competitive energy businesses
Segment Reporting Information [Line Items]
Operating revenues	350	386	998	1,087
Operating revenues | Other
Segment Reporting Information [Line Items]
Operating revenues	(1)	(1)	(1)	(2)
Inter-segment revenues | CECONY
Segment Reporting Information [Line Items]
Operating revenues	(28)	(27)	(82)	(82)
Inter-segment revenues | CECONY | Electric
Segment Reporting Information [Line Items]
Operating revenues	5	4	13	13
Inter-segment revenues | CECONY | Gas
Segment Reporting Information [Line Items]
Operating revenues	1	1	4	4
Inter-segment revenues | CECONY | Steam
Segment Reporting Information [Line Items]
Operating revenues	22	22	65	65
Inter-segment revenues | Competitive energy businesses
Segment Reporting Information [Line Items]
Operating revenues	(2)	(2)	7	(5)
Inter-segment revenues | Other
Segment Reporting Information [Line Items]
Operating revenues	$ 2	$ 2	$ (7)	$ 5

XML

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Detail) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	$ 133	$ 182
Gross Amounts Offset	(117)	(160)
Net Amounts of Assets/ (Liabilities)	16	22
Gross Amounts of Recognized Assets/(Liabilities)	(254)	(389)
Gross Amounts Offset	132	206
Net Amounts of Assets/ (Liabilities)	(122)	(183)
Gross Amounts of Recognized Assets/(Liabilities)	(121)	(207)
Gross Amounts Offset	15	46
Net Amounts of Assets/ (Liabilities)	(106)	(161)
Margin deposits	12	26
Fair Value of Derivative Assets, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	75	59
Gross Amounts Offset	(60)	(41)
Net Amounts of Assets/ (Liabilities)	15	18
Fair Value of Derivative Assets, Assets Held for Sale, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	0	51
Gross Amounts Offset	0	(50)
Net Amounts of Assets/ (Liabilities)	0	1
Fair Value of Derivative Assets, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	58	57
Gross Amounts Offset	(57)	(54)
Net Amounts of Assets/ (Liabilities)	1	3
Fair Value of Derivative Assets, Assets Held for Sale, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	0	15
Gross Amounts Offset	0	(15)
Net Amounts of Assets/ (Liabilities)	0	0
Fair Value of Derivative Liabilities, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(143)	(144)
Gross Amounts Offset	73	78
Net Amounts of Assets/ (Liabilities)	(70)	(66)
Fair Value of Derivative Liabilities, Liabilities Held For Sale, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	0	(115)
Gross Amounts Offset	0	50
Net Amounts of Assets/ (Liabilities)	0	(65)
Fair Value of Derivative Liabilities, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(111)	(102)
Gross Amounts Offset	59	63
Net Amounts of Assets/ (Liabilities)	(52)	(39)
Fair Value of Derivative Liabilities, Liabilities Held For Sale, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	0	(28)
Gross Amounts Offset	0	15
Net Amounts of Assets/ (Liabilities)	0	(13)
CECONY
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	97	88
Gross Amounts Offset	(91)	(79)
Net Amounts of Assets/ (Liabilities)	6	9
Gross Amounts of Recognized Assets/(Liabilities)	(214)	(213)
Gross Amounts Offset	108	127
Net Amounts of Assets/ (Liabilities)	(106)	(86)
Gross Amounts of Recognized Assets/(Liabilities)	(117)	(125)
Gross Amounts Offset	17	48
Net Amounts of Assets/ (Liabilities)	(100)	(77)
Margin deposits	12	26
CECONY | Fair Value of Derivative Assets, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	52	40
Gross Amounts Offset	(46)	(32)
Net Amounts of Assets/ (Liabilities)	6	8
CECONY | Fair Value of Derivative Assets, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	45	48
Gross Amounts Offset	(45)	(47)
Net Amounts of Assets/ (Liabilities)	0	1
CECONY | Fair Value of Derivative Liabilities, Current
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(122)	(121)
Gross Amounts Offset	61	71
Net Amounts of Assets/ (Liabilities)	(61)	(50)
CECONY | Fair Value of Derivative Liabilities, Noncurrent
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets/(Liabilities)	(92)	(92)
Gross Amounts Offset	47	56
Net Amounts of Assets/ (Liabilities)	$ (45)	$ (36)

XML

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (3)	$ (1)	$ 5	$ 0
Total deferred gains/(losses)	(75)	(31)	(149)	(59)
Net deferred gains/(losses)	(78)	(32)	(144)	(59)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(77)	(52)	(163)	(134)
Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(1)	(1)	6	0
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(2)	0	(1)	0
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(19)	8	19	40
Recoverable energy costs
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(39)	(53)	(163)	(92)
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(17)	14	(5)	(7)
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(3)	(1)	1	1
Total deferred gains/(losses)	(67)	(28)	(135)	(52)
Net deferred gains/(losses)	(70)	(29)	(134)	(51)
CECONY | Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(3)	(1)	2	1
CECONY | Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	0	(1)	0
CECONY | Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(18)	8	16	40
CECONY | Recoverable energy costs
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(35)	(49)	(148)	(87)
CECONY | Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(14)	13	(3)	(5)
Non Utility Operating Revenue
Pre-tax gain/(loss) recognized in income
Unrealized gain (loss) on derivatives	(2)		(3)	(3)
Purchased power expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(37)	(31)	(106)	(60)
Unrealized gain (loss) on derivatives	(23)	12	11	6
Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(38)	(26)	(72)	(94)
Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	$ (2)	$ 5	$ 15	$ 20

XML

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Detail)	9 Months Ended
	Sep. 30, 2016 DTH MWh MW gal
Electric Energy Derivative
Derivatives, Fair Value [Line Items]
Electric Energy (MWH) | MWh	22,797,395
Electric Capacity Derivative
Derivatives, Fair Value [Line Items]
Capacity (MW) | MW	15,472
Natural Gas Derivative
Derivatives, Fair Value [Line Items]
Natural Gas (Dt) | DTH	69,954,738
Refined Fuels
Derivatives, Fair Value [Line Items]
Refined fuel (gallons) | gal	1,344,000
CECONY | Electric Energy Derivative
Derivatives, Fair Value [Line Items]
Electric Energy (MWH) | MWh	20,724,225
CECONY | Electric Capacity Derivative
Derivatives, Fair Value [Line Items]
Capacity (MW) | MW	9,000
CECONY | Natural Gas Derivative
Derivatives, Fair Value [Line Items]
Natural Gas (Dt) | DTH	70,100,000
CECONY | Refined Fuels
Derivatives, Fair Value [Line Items]
Refined fuel (gallons) | gal	1,344,000

XML

Derivative Instruments and Hedging Activities - Additional Information (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2016 USD ($)
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 141
Makeup of net credit exposure with commodity exchange brokers	20
Makeup of net credit exposure independent system operators	77
Makeup of net credit exposure with investment-grade counterparties	34
Makeup of net credit exposure non-investment grade/non-rated counterparties	10
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	13
Makeup of net credit exposure with commodity exchange brokers	12
Makeup of net credit exposure with investment-grade counterparties	$ 1

XML

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Detail) $ in Millions	Sep. 30, 2016 USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 111
Collateral posted	24
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	18
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	106
Derivatives in net asset position additional collateral	9
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	10
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	97
Collateral posted	23
CECONY | Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	15
CECONY | Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Derivatives in net liability position additional collateral	$ 84

XML

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 16	$ 22
Derivative liabilities	122	183
CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6	9
Derivative liabilities	106	86
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	365	345
Total liabilities	122	183
Recurring | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	326	311
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	230	187
Total liabilities	3	17
Recurring | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	204	172
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	134	200
Total liabilities	146	286
Recurring | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	115	114
Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	6	14
Total liabilities	5	8
Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	28	47
Derivative liabilities	122	105
Recurring | Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	18	35
Derivative liabilities	106	86
Recurring | Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6	2
Derivative liabilities	3	16
Recurring | Commodity | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4	1
Derivative liabilities	2	14
Recurring | Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	21	25
Derivative liabilities	146	153
Recurring | Commodity | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	7	9
Derivative liabilities	126	129
Recurring | Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6	13
Derivative liabilities	5	1
Recurring | Commodity | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	8
Total assets	1	8
Derivative liabilities	1	0
Recurring | Commodity Contract, Held For Sale
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	1
Derivative liabilities	0	78
Recurring | Commodity Contract, Held For Sale | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0	1
Recurring | Commodity Contract, Held For Sale | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	63
Derivative liabilities	0	133
Recurring | Commodity Contract, Held For Sale | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	1
Derivative liabilities	0	7
Recurring | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	337	297
Recurring | Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	308	276
Recurring | Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	224	185
Recurring | Other | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	200	171
Recurring | Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	113	112
Recurring | Other | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	108	105
Recurring | Other | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Other | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Netting Adjustments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	(5)	(56)
Total liabilities	(32)	(128)
Recurring | Netting Adjustments | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(5)	7
Derivative liabilities	(32)	(65)
Recurring | Netting Adjustments | Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6	17
Total assets	6	17
Derivative liabilities	(23)	(57)
Recurring | Netting Adjustments | Commodity Contract, Held For Sale
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	(63)
Derivative liabilities	0	(63)
Recurring | Netting Adjustments | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Netting Adjustments | Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 0	$ 0

XML

Fair Value Measurements - Schedule of Commodity Derivatives (Detail) $ in Millions	9 Months Ended
	Sep. 30, 2016 USD ($) $ / MWh $ / kW-month
Transmission Congestion Contracts/Financial Transmission Rights
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Forward Energy Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Forward Capacity Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
Minimum | Discount to adjust auction prices for inter-zonal forward price curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	52.80%
Minimum | Discount/premium to adjust auction prices for historical monthly realized settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	(44.90%)
Minimum | Inter-zonal forward price curves adjusted for historical zonal losses
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per kW-month) | $ / MWh	(0.14)
Minimum | Forward Energy Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) | $ / MWh	19.75
Minimum | Forward Capacity Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) | $ / kW-month	2.68
Maximum | Discount to adjust auction prices for inter-zonal forward price curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	59.40%
Maximum | Discount/premium to adjust auction prices for historical monthly realized settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	58.90%
Maximum | Inter-zonal forward price curves adjusted for historical zonal losses
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per kW-month) | $ / MWh	2.82
Maximum | Forward Energy Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) | $ / MWh	80
Maximum | Forward Capacity Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) | $ / kW-month	9.45
Level 3
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Level 3 | Transmission Congestion Contracts/Financial Transmission Rights
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	1
Level 3 | Forward Energy Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(1)
Level 3 | Forward Capacity Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
CECONY | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
CECONY | Transmission Congestion Contracts
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Valuation Techniques	Discounted Cash Flow
CECONY | Minimum | Discount to adjust auction prices for inter-zonal forward price curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	52.80%
CECONY | Minimum | Discount/premium to adjust auction prices for historical monthly realized settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	(44.90%)
CECONY | Minimum | Forward Energy Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) | $ / MWh	21.10
CECONY | Maximum | Discount to adjust auction prices for inter-zonal forward price curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	59.40%
CECONY | Maximum | Discount/premium to adjust auction prices for historical monthly realized settlements
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range in percentage	58.90%
CECONY | Maximum | Forward Energy Prices | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWH) | $ / MWh	80
CECONY | Level 3
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 0
CECONY | Level 3 | Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(1)
CECONY | Level 3 | Transmission Congestion Contracts
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1

XML

Fair Value Measurements - Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 5	$ 13	$ 6	$ 20
Included in earnings	(4)	(4)	(1)	(18)
Included in regulatory assets and liabilities	(5)	(1)	(11)	(1)
Purchases	0	1	2	9
Sales	4	0	4	0
Settlements	1	(5)	1	(6)
Ending balance	1	4	1	4
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	2	11	8	13
Included in earnings	0	(1)	(1)	(5)
Included in regulatory assets and liabilities	(3)	(1)	(6)	(1)
Purchases	0	1	1	5
Sales	0	0	0	0
Settlements	1	(2)	(2)	(4)
Ending balance	$ 0	$ 8	$ 0	$ 8

XML

Fair Value Measurements - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Purchased power expense
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value, assets measured on recurring basis, change in unrealized gain (loss)	$ (4)	$ (3)	$ (2)	$ (8)
Competitive energy businesses
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative liabilities	$ (5)	$ (3)	$ (6)	$ (12)

XML

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

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Variable Interest Entities - Summary of VIEs (Detail)	9 Months Ended
	Sep. 30, 2016 USD ($) MW	Oct. 31, 2016
Variable Interest Entity, Not Primary Beneficiary, Aggregated Disclosure
Variable Interest Entity [Line Items]
Percentage of variable interests	50.00%
Variable Interest Entity, Not Primary Beneficiary | Copper Mountain Solar 3 | Nevada
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW	128
Power Purchase Agreement Term (in Years)	20 years
Year of Initial Investment	2014
Maximum exposure to loss	$ 179,000,000
Variable Interest Entity, Not Primary Beneficiary | Panoche Valley | California
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW	120
Power Purchase Agreement Term (in Years)	20 years
Year of Initial Investment	2015
Maximum exposure to loss	$ 274,000,000
Variable Interest Entity, Not Primary Beneficiary | Mesquite Solar 1 | Arizona
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW	83
Power Purchase Agreement Term (in Years)	20 years
Year of Initial Investment	2013
Maximum exposure to loss	$ 107,000,000
Variable Interest Entity, Not Primary Beneficiary | Copper Mountain Solar 2 | Nevada
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW	75
Power Purchase Agreement Term (in Years)	25 years
Year of Initial Investment	2013
Maximum exposure to loss	$ 84,000,000
Variable Interest Entity, Not Primary Beneficiary | California Solar | California
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW	55
Power Purchase Agreement Term (in Years)	25 years
Year of Initial Investment	2012
Maximum exposure to loss	$ 70,000,000
Variable Interest Entity, Not Primary Beneficiary | Broken Bow II | Nebraska
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW	38
Power Purchase Agreement Term (in Years)	25 years
Year of Initial Investment	2014
Maximum exposure to loss	$ 51,000,000
Variable Interest Entity, Primary Beneficiary | Texas Solar 4
Variable Interest Entity [Line Items]
Percentage of variable interests	80.00%
VIEs, noncontrolling interest	$ 8,000,000
Variable Interest Entity, Primary Beneficiary | Texas Solar 4 | Texas
Variable Interest Entity [Line Items]
Generating Capacity (MWs AC) | MW	32
Power Purchase Agreement Term (in Years)	25 years
Year of Initial Investment	2014
Maximum exposure to loss	$ 43,000,000
Scenario, Forecast | Panoche Valley | California
Variable Interest Entity [Line Items]
Voting interest acquired (percentage)		50.00%

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Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		4 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2016	Sep. 30, 2015	Oct. 31, 2016	Jun. 30, 2016	May 31, 2016	Jan. 31, 2016	Dec. 31, 2014
Related Party Transaction [Line Items]
Ownership interest, percentage										45.70%
Costs of gas purchased	$ 81	$ 64		$ 320	$ 415
Loss on derivative	77	52		163	134
CECONY | Financial Electric Capacity Contract
Related Party Transaction [Line Items]
Loss on derivative	1			1
CECONY
Related Party Transaction [Line Items]
Costs of gas purchased	34	$ 30		217	$ 282
CET Electric
Related Party Transaction [Line Items]
Ownership interest, percentage								45.70%	45.70%
Stagecoach Gas Services LLC
Related Party Transaction [Line Items]
Equity method ownership (percent)							50.00%
Stagecoach Gas Services LLC | CECONY | Equity Method Investee | Purchased Power Costs
Related Party Transaction [Line Items]
Costs of gas purchased	10		$ 8
Panoche Valley | Equity Method Investee
Related Party Transaction [Line Items]
Notes receivable from related parties	$ 234		$ 234	$ 234
Equity method ownership (percent)	50.00%		50.00%	50.00%
California | Scenario, Forecast | Panoche Valley
Related Party Transaction [Line Items]
Voting interest acquired (percentage)						50.00%
California | Scenario, Forecast | Panoche Valley
Related Party Transaction [Line Items]
Voting interest acquired (percentage)						50.00%

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Acquisitions, Investments and Dispositions - Additional Information (Details) $ in Millions		1 Months Ended						3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2015 USD ($)	Oct. 31, 2016 USD ($) MW	Sep. 30, 2016 USD ($)	Aug. 31, 2016 USD ($)	Jun. 30, 2016 USD ($)	May 31, 2016 USD ($)	Jan. 31, 2016 USD ($) MW	Sep. 30, 2016 USD ($)	Sep. 30, 2015 USD ($)	Sep. 30, 2016 USD ($) MW	Sep. 30, 2015 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2015 USD ($)	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Ownership interest, percentage														45.70%
Non-utility property			$ 1,127					$ 1,127		$ 1,127			$ 832
Other current assets			206					206		206			191
Gain on sale of business								104	$ 0	104	$ 0
Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership (percent)							12.50%
Payments to acquire equity method investments							$ 18
Equity method investments			41					41		41
Stagecoach Gas Services LLC
Schedule of Equity Method Investments [Line Items]
Equity method ownership (percent)					50.00%
Payments to acquire equity method investments					$ 945
Equity method investments			968					968		$ 968
Pilesgrove
Schedule of Equity Method Investments [Line Items]
Equity method ownership (percent)					50.00%
Impairment of investment					$ 8
Impairment of investment, net of tax					$ 5
New Jersey | Pilesgrove
Schedule of Equity Method Investments [Line Items]
Generating capacity | MW										18
Texas Solar 7 | Texas
Schedule of Equity Method Investments [Line Items]
Voting interest acquired (percentage)							100.00%
Generating capacity | MW							106
Payments to acquire business							$ 227
Non-utility construction work in progress							218
Other receivables							$ 9
Pilesgrove
Schedule of Equity Method Investments [Line Items]
Voting interest acquired (percentage)				50.00%
Net assets of project			48					48		$ 48
Non-utility property			45					45		45
Consideration transferred				$ 16
Bargain purchase gain				8
Bargain purchase gain, net of tax				5
Other current assets			3					3		3
Electric | Texas Solar 7 | Texas
Schedule of Equity Method Investments [Line Items]
Net assets of project			123					123		123
Scenario, Forecast | Panoche Valley | California
Schedule of Equity Method Investments [Line Items]
Voting interest acquired (percentage)		50.00%
Generating capacity | MW		240
Consideration transferred		$ 37
Scenario, Forecast | Gas | Minimum | Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments												$ 3,000
Scenario, Forecast | Gas | Maximum | Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments												$ 3,500
CET Electric
Schedule of Equity Method Investments [Line Items]
Ownership interest, percentage						45.70%	45.70%
CET Electric | NY Transco
Schedule of Equity Method Investments [Line Items]
Equity method investments			53					$ 53		$ 53
Purchase Price of TOTS Project Transfer | NY Transco | CET Electric
Schedule of Equity Method Investments [Line Items]
Related party transaction, amount of transaction						$ 122
Lease Payments | NY Transco | CET Electric
Schedule of Equity Method Investments [Line Items]
Expenses from transactions with related party						$ 8
Discontinued Operations, Held-for-sale | Pike
Schedule of Equity Method Investments [Line Items]
Impairment of long-lived assets to be disposed of	$ 5
Impairment of long-lived assets to be disposed of, net of taxes	$ 3
Assets held for sale													23
Liabilities held for sale													5
Discontinued Operations, Held-for-sale | Retail Electric Supply Business
Schedule of Equity Method Investments [Line Items]
Assets held for sale													134
Liabilities held for sale													$ 84
Discontinued Operations, Disposed of by Sale | Pike
Schedule of Equity Method Investments [Line Items]
Proceeds from divestiture of business				$ 15
Discontinued Operations, Disposed of by Sale | Pike | O&R
Schedule of Equity Method Investments [Line Items]
Period for transition services (up to)				18 months
Agreement to purchase and sell, term				3 years
Agreement to purchase and sell, term of extension option				3 years
Discontinued Operations, Disposed of by Sale | Retail Electric Supply Business
Schedule of Equity Method Investments [Line Items]
Proceeds from divestiture of business			235
Gain on sale of business			104
Gain on sale of business, after tax			47
Gain on sale of derivatives			65
Gain on sale of derivatives, after tax			42
Tax effect of sale, state tax related to change in apportionment of state income taxes			29
Tax effect of sale, state tax related to change in apportionment of state income taxes, net of federal tax			$ 19