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, 2011

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 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)	Yes x	No ¨
Consolidated Edison of New York, Inc. (CECONY)	Yes x	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	Yes x	No ¨
CECONY	Yes x	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 filer x	Accelerated filer ¨	Non-accelerated filer ¨	Smaller reporting company ¨
CECONY
Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filer x	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 ¨	No x
CECONY	Yes ¨	No x

As of October 28, 2011, Con Edison had outstanding 292,904,646 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 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 frequently used 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.
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 Quasi-governmental Not-for-Profits
EPA	U. S. Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
IRS	Internal Revenue Service
ISO-NE	ISO New England Inc.
NJBPU	New Jersey Board of Public Utilities
NJDEP	New Jersey Department of Environmental Protection
NYAG	New York State Attorney General
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
ABO	Accumulated Benefit Obligation
ASU	Accounting Standards Update
FASB	Financial Accounting Standards Board
LILO	Lease In/Lease Out
OCI	Other Comprehensive Income
SFAS	Statement of Financial Accounting Standards
SSCM	Simplified service cost method
VIE	Variable interest entity
Environmental
CO2	Carbon dioxide
GHG	Greenhouse gases
MGP Sites	Manufactured gas plant sites
PCBs	Polychlorinated biphenyls
PRP	Potentially responsible party
SO2	Sulfur dioxide
Superfund	Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes

2

Units of Measure
dths	Dekatherms
kV	Kilovolts
kWh	Kilowatt-hour
mdths	Thousand dekatherms
MMlbs	Million pounds
MVA	Megavolt amperes
MW	Megawatts or thousand kilowatts
MWH	Megawatt hour
Other
AFDC	Allowance for funds used during construction
COSO	Committee of Sponsoring Organizations of the Treadway Commission
EMF	Electric and magnetic fields
ERRP	East River Repowering Project
Fitch	Fitch Ratings
First Quarter Form 10-Q	The Companies’ combined Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2011
Form 10-K	The Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2010
LTIP	Long Term Incentive Plan
Moody’s	Moody’s Investors Service
S&P	Standard & Poor’s Rating Services
Second Quarter Form 10-Q	The Companies’ combined Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2011
Third Quarter Form 10-Q	The Companies’ combined Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2011
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 Cash Flows		7
	Consolidated Balance Sheet		8
	Consolidated Statement of Comprehensive Income		10
	Consolidated Statement of Common Shareholders’ Equity		11
	CECONY
	Consolidated Income Statement		12
	Consolidated Statement of Cash Flows		13
	Consolidated Balance Sheet		14
	Consolidated Statement of Common Shareholder’s Equity		16
	Notes to Financial Statements (Unaudited)		17
ITEM  2	Management’s Discussion and Analysis of Financial Condition and Results of Operations		38
ITEM  3	Quantitative and Qualitative Disclosures About Market Risk		60
ITEM  4	Controls and Procedures		60
PART II—Other Information
ITEM  1	Legal Proceedings		61
ITEM 1A	Risk Factors		61
ITEM  2	Unregistered Sales of Equity Securities and Use of Proceeds		61
ITEM  6	Exhibits		62
	Signatures		63

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 “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 risks, including:

• the failure to operate energy facilities safely and reliably could adversely affect the Companies;

• the failure to properly complete construction projects could adversely affect the Companies;

• the failure of processes and systems and the performance of employees and contractors could adversely affect the Companies;

• 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 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 Internal Revenue Service has disallowed substantial tax deductions taken by the company;

• a cyber attack could adversely affect the Companies; and

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

5

Consolidated Edison, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2011			2010			2011			2010
	(Millions of Dollars/Except Share Data)
OPERATING REVENUES
Electric		$2,861			$2,814			$6,883			$6,959
Gas		220			229			1,309			1,276
Steam		76			91			508			487
Non-utility		472			573			1,272			1,463
TOTAL OPERATING REVENUES		3,629			3,707			9,972			10,185
OPERATING EXPENSES
Purchased power		1,239			1,425			3,124			3,708
Fuel		73			106			317			342
Gas purchased for resale		73			73			491			482
Other operations and maintenance		783			738			2,213			2,117
Depreciation and amortization		222			211			659			626
Taxes, other than income taxes		483			449			1,387			1,283
TOTAL OPERATING EXPENSES		2,873			3,002			8,191			8,558
OPERATING INCOME		756			705			1,781			1,627
OTHER INCOME (DEDUCTIONS)
Investment and other income		—			9			19			29
Allowance for equity funds used during construction		2			4			8			13
Other deductions		(3	)		(3	)		(14	)		(12	)
TOTAL OTHER INCOME (DEDUCTIONS)		(1	)		10			13			30
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE		755			715			1,794			1,657
INTEREST EXPENSE
Interest on long-term debt		145			152			437			450
Other interest		—			7			15			13
Allowance for borrowed funds used during construction		(1	)		(2	)		(4	)		(7	)
NET INTEREST EXPENSE		144			157			448			456
INCOME BEFORE INCOME TAX EXPENSE		611			558			1,346			1,201
INCOME TAX EXPENSE		225			205			477			433
NET INCOME		386			353			869			768
Preferred stock dividend requirements of subsidiary		(3	)		(3	)		(9	)		(9	)
NET INCOME FOR COMMON STOCK		$   383			$   350			$   860			$   759
Net income for common stock per common share – basic		$  1.31			$  1.24			$  2.94			$  2.69
Net income for common stock per common share – diluted		$  1.30			$  1.23			$  2.92			$  2.68
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK		$0.600			$0.595			$1.800			$1.785
AVERAGE NUMBER OF SHARES OUTSTANDING – BASIC (IN MILLIONS)		292.9			283.0			292.5			282.2
AVERAGE NUMBER OF SHARES OUTSTANDING – DILUTED (IN MILLIONS)		294.6			284.6			294.2			283.7

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

6

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Nine Months Ended September 30,
	2011			2010
	(Millions of Dollars)
OPERATING ACTIVITIES
Net Income	$	869		$	768
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization		659			626
Deferred income taxes		368			562
Common equity component of allowance for funds used during construction		(8	)		(13	)
Net derivative (gains)/losses		(25	)		35
Other non-cash items (net)		45			(8	)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers, less allowance for uncollectibles		(4	)		(114	)
Materials and supplies, including fuel oil and gas in storage		(27	)		(9	)
Other receivables and other current assets		70			(114	)
Prepayments		(128	)		(473	)
Accounts payable		(50	)		(105	)
Pensions and retiree benefits		(1	)		(33	)
Accrued taxes		76			63
Accrued interest		57			45
Deferred charges, deferred derivative losses, noncurrent assets and other regulatory assets		92			(472	)
Deferred credits and other regulatory liabilities		158			142
Other assets		—			(8	)
Other liabilities		10			82
NET CASH FLOWS FROM OPERATING ACTIVITIES		2,161			974
INVESTING ACTIVITIES
Utility construction expenditures		(1,412	)		(1,455	)
Cost of removal less salvage		(123	)		(103	)
Non-utility construction expenditures		(57	)		(6	)
Proceeds from investment tax credits and grants related to renewable energy investments		4			—
Net investment in Pilesgrove solar project		(31	)		(3	)
Common equity component of allowance for funds used during construction		8			13
Purchase of additional ownership interest in Honeoye Storage Corporation		—			(12	)
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(1,611	)		(1,566	)
FINANCING ACTIVITIES
Net proceeds from short-term debt		—			846
Issuance of long-term debt		—			870
Retirement of long-term debt		(3	)		(781	)
Issuance of common stock		81			78
Repurchase of common stock		(40	)		—
Debt issuance costs		—			(6	)
Common stock dividends		(519	)		(468	)
Preferred stock dividends		(9	)		(9	)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES		(490	)		530
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD		60			(62	)
BALANCE AT BEGINNING OF PERIOD		338			260
BALANCE AT END OF PERIOD	$	398		$	198
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash paid/(refunded) during the period for:
Interest	$	371		$	394
Income taxes	$	(132	)	$	284

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

7

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2011		December 31, 2010
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$	398	$	338
Accounts receivable – customers, less allowance for uncollectible accounts of $88 and $76 in 2011 and 2010, respectively		1,177		1,173
Accrued unbilled revenue		479		633
Other receivables, less allowance for uncollectible accounts of $9 and $8 in 2011 and 2010, respectively		297		293
Fuel oil, gas in storage, materials and supplies, at average cost		375		348
Prepayments		469		341
Regulatory assets		110		203
Other current assets		153		178
TOTAL CURRENT ASSETS		3,458		3,507
INVESTMENTS		474		403
UTILITY PLANT, AT ORIGINAL COST
Electric		20,714		19,851
Gas		4,566		4,344
Steam		1,960		2,038
General		1,907		1,911
TOTAL		29,147		28,144
Less: Accumulated depreciation		5,961		5,808
Net		23,186		22,336
Construction work in progress		1,404		1,458
NET UTILITY PLANT		24,590		23,794
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $57 and $51 in 2011 and 2010, respectively		47		46
Construction work in progress		61		23
NET PLANT		24,698		23,863
OTHER NONCURRENT ASSETS
Goodwill		429		429
Intangible assets, less accumulated amortization of $3 in 2011 and 2010		3		3
Regulatory assets		7,206		7,683
Other deferred charges and noncurrent assets		267		298
TOTAL OTHER NONCURRENT ASSETS		7,905		8,413
TOTAL ASSETS	$	36,535	$	36,186

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

8

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2011		December 31, 2010
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$	305	$	5
Accounts payable		1,062		1,151
Customer deposits		302		289
Accrued taxes		166		90
Accrued interest		212		155
Accrued wages		94		102
Fair value of derivative liabilities		101		125
Regulatory liabilities		257		295
Other current liabilities		460		459
TOTAL CURRENT LIABILITIES		2,959		2,671
NONCURRENT LIABILITIES
Obligations under capital leases		2		7
Provision for injuries and damages		180		165
Pensions and retiree benefits		2,600		3,287
Superfund and other environmental costs		496		512
Asset retirement obligations		114		109
Fair value of derivative liabilities		30		77
Other noncurrent liabilities		118		113
TOTAL NONCURRENT LIABILITIES		3,540		4,270
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits		7,110		6,602
Regulatory liabilities		821		652
Other deferred credits		69		46
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES		8,000		7,300
LONG-TERM DEBT		10,369		10,671
SHAREHOLDERS’ EQUITY
Common shareholders’ equity (See Statement of Shareholders’ Equity)		11,454		11,061
Preferred stock of subsidiary		213		213
TOTAL SHAREHOLDERS’ EQUITY		11,667		11,274
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	36,535	$	36,186

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

9

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2011			2010			2011			2010
	(Millions of Dollars)
NET INCOME	$	386		$	353		$	869		$	768
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension plan liability adjustments, net of taxes of $1 and $4 in 2011 and $1 and $4 in 2010, respectively		2			1			7			5
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES		2			1			7			5
COMPREHENSIVE INCOME	$	388		$	354		$	876		$	773
Preferred stock dividend requirements of subsidiary		(3	)		(3	)		(9	)		(9	)
COMPREHENSIVE INCOME FOR COMMON STOCK	$	385		$	351		$	867		$	764

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

10

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF COMMON SHAREHOLDERS’ EQUITY (UNAUDITED)

	Common Stock				Additional Paid-In Capital		Retained Earnings			Treasury Stock						Capital Stock Expense			Accumulated Other Comprehensive Income/(Loss)			Total
(Millions of Dollars/Except Share Data)	Shares		Amount							Shares			Amount
BALANCE AS OF DECEMBER 31, 2009		281,123,741	$	30	$	4,420	$	6,904			23,210,700		$	(1,001	)	$	(62	)	$	(42	)	$	10,249
Net income for common stock								226															226
Common stock dividends								(167	)														(167	)
Issuance of common shares – dividend reinvestment and employee stock plans		647,731				28																	28
Other comprehensive income																				3			3
BALANCE AS OF MARCH 31, 2010		281,771,472	$	30	$	4,448	$	6,963			23,210,700		$	(1,001	)	$	(62	)	$	(39	)	$	10,339
Net income for common stock								183															183
Common stock dividends								(168	)														(168	)
Issuance of common shares – dividend reinvestment and employee stock plans		555,964				25																	25
Other comprehensive income																				1			1
BALANCE AS OF JUNE 30, 2010		282,327,436	$	30	$	4,473	$	6,978			23,210,700		$	(1,001	)	$	(62	)	$	(38	)	$	10,380
Net income for common stock								350															350
Common stock dividends								(168	)														(168	)
Issuance of common shares – dividend reinvestment and employee stock plans		1,487,598		1		66																	67
Other comprehensive income																				1			1
BALANCE AS OF SEPTEMBER 30, 2010		283,815,034	$	31	$	4,539	$	7,160			23,210,700		$	(1,001	)	$	(62	)	$	(37	)	$	10,630
BALANCE AS OF DECEMBER 31, 2010		291,616,334	$	31	$	4,915	$	7,220			23,210,700		$	(1,001	)	$	(64	)	$	(40	)	$	11,061
Net income for common stock								311															311
Common stock dividends								(175	)														(175	)
Issuance of common shares – dividend reinvestment and employee stock plans		656,049		1		30																	31
Other comprehensive income																				3			3
BALANCE AS OF MARCH 31, 2011		292,272,383	$	32	$	4,945	$	7,356			23,210,700		$	(1,001	)	$	(64	)	$	(37	)	$	11,231
Net income for common stock								165															165
Common stock dividends								(175	)														(175	)
Issuance of common shares – dividend reinvestment and employee stock plans		603,513				32					(182,942	)		5									37
Common stock repurchases											178,942			(9	)								(9	)
Other comprehensive income																				2			2
BALANCE AS OF JUNE 30, 2011		292,875,896	$	32	$	4,977	$	7,346			23,206,700		$	(1,005	)	$	(64	)	$	(35	)	$	11,251
Net income for common stock								383															383
Common stock dividends								(176	)														(176	)
Issuance of common shares – dividend reinvestment and employee stock plans		8,000				6					(554,356	)		19									25
Common stock repurchases											546,356			(31	)								(31	)
Other comprehensive income																				2			2
BALANCE AS OF SEPTEMBER 30, 2011		292,883,896	$	32	$	4,983	$	7,553			23,198,700		$	(1,017	)	$	(64	)	$	(33	)	$	11,454

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,
	2011			2010			2011			2010
	(Millions of Dollars)
OPERATING REVENUES
Electric	$	2,644		$	2,570		$	6,378		$	6,402
Gas		197			204			1,156			1,126
Steam		76			91			508			487
TOTAL OPERATING REVENUES		2,917			2,865			8,042			8,015
OPERATING EXPENSES
Purchased power		736			764			1,840			2,102
Fuel		73			105			317			343
Gas purchased for resale		57			63			412			408
Other operations and maintenance		678			637			1,906			1,832
Depreciation and amortization		209			198			618			586
Taxes, other than income taxes		462			432			1,330			1,232
TOTAL OPERATING EXPENSES		2,215			2,199			6,423			6,503
OPERATING INCOME		702			666			1,619			1,512
OTHER INCOME (DEDUCTIONS)
Investment and other income		(6	)		5			3			23
Allowance for equity funds used during construction		1			3			6			10
Other deductions		(3	)		(2	)		(12	)		(11	)
TOTAL OTHER INCOME (DEDUCTIONS)		(8	)		6			(3	)		22
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE		694			672			1,616			1,534
INTEREST EXPENSE
Interest on long-term debt		130			137			393			406
Other interest		4			5			13			13
Allowance for borrowed funds used during construction		(1	)		(1	)		(3	)		(6	)
NET INTEREST EXPENSE		133			141			403			413
INCOME BEFORE INCOME TAX EXPENSE		561			531			1,213			1,121
INCOME TAX EXPENSE		205			196			425			404
NET INCOME		356			335			788			717
Preferred stock dividend requirements		(3	)		(3	)		(9	)		(8	)
NET INCOME FOR COMMON STOCK	$	353		$	332		$	779		$	709

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

12

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Nine Months Ended September 30,
	2011			2010
	(Millions of Dollars)
OPERATING ACTIVITIES
Net income	$	788		$	717
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization		618			586
Deferred income taxes		309			562
Common equity component of allowance for funds used during construction		(6	)		(10	)
Other non-cash items (net)		98			(88	)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers, less allowance for uncollectibles		3			(84	)
Materials and supplies, including fuel oil and gas in storage		2			(9	)
Other receivables and other current assets		243			(208	)
Prepayments		(303	)		(309	)
Accounts payable		(45	)		(96	)
Pensions and retiree benefits		(5	)		(30	)
Accrued taxes		(7	)		20
Accrued interest		46			37
Deferred charges, deferred derivative losses, noncurrent assets and other regulatory assets		33			(374	)
Deferred credits and other regulatory liabilities		167			131
Other liabilities		19			93
NET CASH FLOWS FROM OPERATING ACTIVITIES		1,960			938
INVESTING ACTIVITIES
Utility construction expenditures		(1,338	)		(1,371	)
Cost of removal less salvage		(118	)		(100	)
Common equity component of allowance for funds used during construction		6			10
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(1,450	)		(1,461	)
FINANCING ACTIVITIES
Net proceeds from short-term debt		—			832
Issuance of long-term debt		—			700
Retirement of long-term debt		—			(625	)
Debt issuance costs		—			(6	)
Capital contribution by parent		—			36
Dividend to parent		(509	)		(502	)
Preferred stock dividends		(9	)		(8	)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES		(518	)		427
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD		(8	)		(96	)
BALANCE AT BEGINNING OF PERIOD		78			131
BALANCE AT END OF PERIOD	$	70		$	35
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash paid/(refunded) during the period for:
Interest	$	336		$	357
Income taxes	$	(103	)	$	263

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

13

Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2011		December 31, 2010
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$	70	$	78
Accounts receivable – customers, less allowance for uncollectible accounts of $80 and $68 in 2011 and 2010, respectively		1,022		1,025
Other receivables, less allowance for uncollectible accounts of $8 and $7 in 2011 and 2010, respectively		82		73
Accrued unbilled revenue		358		473
Accounts receivable from affiliated companies		24		273
Fuel oil, gas in storage, materials and supplies, at average cost		304		306
Prepayments		385		82
Regulatory assets		90		151
Other current assets		90		104
TOTAL CURRENT ASSETS		2,425		2,565
INVESTMENTS		178		167
UTILITY PLANT, AT ORIGINAL COST
Electric		19,508		18,735
Gas		4,051		3,844
Steam		1,960		2,038
General		1,736		1,746
TOTAL		27,255		26,363
Less: Accumulated depreciation		5,443		5,314
Net		21,812		21,049
Construction work in progress		1,333		1,345
NET UTILITY PLANT		23,145		22,394
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $23 and $22 in 2011 and 2010, respectively		6		7
NET PLANT		23,151		22,401
OTHER NONCURRENT ASSETS
Regulatory assets		6,668		7,097
Other deferred charges and noncurrent assets		232		244
TOTAL OTHER NONCURRENT ASSETS		6,900		7,341
TOTAL ASSETS	$	32,654	$	32,474

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, 2011		December 31, 2010
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$	300	$	—
Accounts payable		836		924
Accounts payable to affiliated companies		15		13
Customer deposits		289		276
Accrued taxes		27		34
Accrued taxes to affiliated companies		29		29
Accrued interest		176		130
Accrued wages		91		93
Fair value of derivative liabilities		51		71
Regulatory liabilities		230		267
Other current liabilities		407		400
TOTAL CURRENT LIABILITIES		2,451		2,237
NONCURRENT LIABILITIES
Obligations under capital leases		2		7
Provision for injuries and damages		173		159
Pensions and retiree benefits		2,259		2,900
Superfund and other environmental costs		377		392
Asset retirement obligations		114		109
Fair value of derivative liabilities		9		29
Other noncurrent liabilities		110		102
TOTAL NONCURRENT LIABILITIES		3,044		3,698
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits		6,539		6,071
Regulatory liabilities		706		547
Other deferred credits		65		42
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES		7,310		6,660
LONG-TERM DEBT		9,444		9,743
SHAREHOLDER’S EQUITY
Common shareholder’s equity (See Statement of Shareholder’s Equity)		10,192		9,923
Preferred stock		213		213
TOTAL SHAREHOLDER’S EQUITY		10,405		10,136
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$	32,654	$	32,474

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

15

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF COMMON 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
(Millions of Dollars/Except Share Data)	Shares		Amount
BALANCE AS OF DECEMBER 31, 2009		235,488,094	$	589	$	3,877	$	5,909		$	(962	)	$	(62	)	$	(4	)	$	9,347
Net income								246												246
Capital contribution from parent						12														12
Common stock dividend to parent								(167	)											(167	)
Cumulative preferred dividends								(3	)											(3	)
BALANCE AS OF MARCH 31, 2010		235,488,094	$	589	$	3,889	$	5,985		$	(962	)	$	(62	)	$	(4	)	$	9,435
Net income								138												138
Capital contribution from parent						12														12
Common stock dividend to parent								(168	)											(168	)
Cumulative preferred dividends								(3	)											(3	)
BALANCE AS OF JUNE 30, 2010		235,488,094	$	589	$	3,901	$	5,952		$	(962	)	$	(62	)	$	(4	)	$	9,414
Net income								335												335
Capital contribution from parent						12														12
Common stock dividend to parent								(167	)											(167	)
Cumulative preferred dividends								(3	)											(3	)
BALANCE AS OF SEPTEMBER 30, 2010		235,488,094	$	589	$	3,913	$	6,117		$	(962	)	$	(62	)	$	(4	)	$	9,591
BALANCE AS OF DECEMBER 31, 2010		235,488,094	$	589	$	4,234	$	6,132		$	(962	)	$	(64	)	$	(6	)	$	9,923
Net income								271												271
Common stock dividend to parent								(170	)											(170	)
Cumulative preferred dividends								(3	)											(3	)
BALANCE AS OF MARCH 31, 2011		235,488,094	$	589	$	4,234	$	6,230		$	(962	)	$	(64	)	$	(6	)	$	10,021
Net income								160												160
Common stock dividend to parent								(170	)											(170	)
Cumulative preferred dividends								(3	)											(3	)
BALANCE AS OF JUNE 30, 2011		235,488,094	$	589	$	4,234	$	6,217		$	(962	)	$	(64	)	$	(6	)	$	10,008
Net income								356												356
Common stock dividend to parent								(169	)											(169	)
Cumulative preferred dividends								(3	)											(3	)
BALANCE AS OF SEPTEMBER 30, 2011		235,488,094	$	589	$	4,234	$	6,401		$	(962	)	$	(64	)	$	(6	)	$	10,192

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

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NOTES TO THE FINANCIAL STATEMENTS (UNAUDITED)

General

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

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

The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies’ separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2010 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2011 and June 30, 2011. Certain prior period amounts have been reclassified to conform to the current period presentation.

Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiaries, provides electric service in southeastern New York and adjacent areas of northern New Jersey and eastern Pennsylvania and gas service in southeastern New York and adjacent areas of eastern Pennsylvania. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a retail energy services company that sells electricity and also offers energy-related services; Consolidated Edison Energy, Inc. (Con Edison Energy), a wholesale energy supply and services company; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops and participates in infrastructure projects.

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Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

For the three and nine months ended September 30, 2011 and 2010, Con Edison’s basic and diluted 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)	2011		2010		2011		2010
Net income for common stock	$	383	$	350	$	860	$	759
Weighted average common shares outstanding – Basic		292.9		283.0		292.5		282.2
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.6		1.7		1.5
Adjusted weighted average common shares outstanding – Diluted		294.6		284.6		294.2		283.7
Net income for common stock per common share – basic	$	1.31	$	1.24	$	2.94	$	2.69
Net income for common stock per common share – diluted	$	1.30	$	1.23	$	2.92	$	2.68

Note B — Regulatory Matters

Rate Agreements

O&R — Electric

In June 2011, the NYSPSC adopted an order granting O&R an electric rate increase, effective July 1, 2011, of $26.6 million. The NYSPSC ruling reflects the following major items:

• a weighted average cost of capital of 7.22 percent, reflecting:

• a return on common equity of 9.2 percent, assuming achievement by the company of $825,000 of austerity measures;

• cost of long-term debt of 5.50 percent; and

• common equity ratio of 48 percent.

• continuation of a revenue decoupling mechanism;

• a provision for reconciliation of certain differences in actual average net utility plant to the amount reflected in rates ($718 million) and continuation of rate provisions under which pension and other post-retirement benefit expenses, environmental remediation expenses, tax-exempt debt costs and certain other expenses are reconciled to amounts for those expenses reflected in rates;

• continuation of the rate provisions pursuant to which the company recovers its purchased power costs from customers;

• discontinuation of the provisions under which property taxes were reconciled to amounts reflected in rates;

• discontinuation of the inclusion in rates of funding for the company’s annual incentive plan for non-officer management employees;

• continuation of provisions for potential operations penalties of up to $3 million annually if certain customer service and system reliability performance targets are not met; and

• O&R is directed to produce a report detailing its implementation plans for the recommendations made in connection with the NYSPSC’s management audit of CECONY, with a forecast of costs to achieve and expected savings.

On July 29, 2011, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective July 1, 2012, of $17.7 million. The filing reflects a return on common equity of 10.75 percent and a common equity ratio of 49.4 percent. Among other things, the filing proposes continuation of the current provisions with respect to recovery from customers of the cost of purchased power and with respect to the deferral of differences between actual expenses allocable to the electric business for pensions and other postretirement benefits, environmental, and research and developmental costs to the amounts for such costs reflected in electric rates. The filing also includes an alternative proposal for a three-year electric rate plan with annual rate increases of $17.6 million effective July 2012, 2013 and 2014. The multi-year filing reflects a return on common equity of 11.25 percent.

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Other Regulatory Matters

In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures (see “Investigations of Vendor Payments” in Note G). Pursuant to NYSPSC orders, a portion of the company’s revenues (currently, $249 million, $32 million and $6 million on an annual basis for electric, gas and steam service, respectively) is being collected subject to potential refund to customers. At September 30, 2011, the company had collected an estimated $753 million from customers subject to potential refund in connection with this proceeding. In October 2010, a NYSPSC consultant reported its $21 million provisional assessment, which the company has disputed, of potential overcharges for construction work. The potential overcharges related to transactions that involved certain employees who were arrested and a contractor that performed work for the company. The NYSPSC’s consultant is expected to continue to review the company’s expenditures. At September 30, 2011, the company had a $10.5 million regulatory liability relating to this matter. The company is unable to estimate the amount, if any, by which any refund required by the NYSPSC may exceed this regulatory liability.

In February 2011, the NYSPSC initiated a proceeding to examine the existing mechanisms pursuant to which utilities recover site investigation and remediation costs and possible alternatives. See Note F to the Third Quarter Financial Statements.

19

Regulatory Assets and Liabilities

Regulatory assets and liabilities at September 30, 2011 and December 31, 2010 were comprised of the following items:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Regulatory assets
Unrecognized pension and other postretirement costs	$	3,769	$	4,371	$	3,584	$	4,152
Future federal income tax		1,763		1,593		1,688		1,515
Environmental remediation costs		681		695		563		574
Pension and other post retirement benefits deferrals		198		138		156		90
Revenue taxes		160		145		155		140
Surcharge for New York State assessment		150		121		138		112
Net electric deferrals		126		156		126		156
Deferred storm costs		81		57		61		43
O&R transition bond charges		45		48		—		—
Deferred derivative losses – long-term		34		74		21		48
Workers’ compensation		25		31		24		31
Accrued unbilled revenues		22		—		22		—
Property tax reconciliation		12		34		—		27
World Trade Center restoration costs		9		45		9		45
Recoverable energy cost		2		42		2		42
Other		129		133		119		122
Regulatory assets – long-term		7,206		7,683		6,668		7,097
Deferred derivative losses – current		110		190		90		151
Recoverable energy costs – current		—		13		—		—
Regulatory assets – current		110		203		90		151
Total Regulatory Assets	$	7,316	$	7,886	$	6,758	$	7,248
Regulatory liabilities
Allowance for cost of removal less salvage	$	440	$	422	$	365	$	350
World Trade Center settlement proceeds		62		—		62		—
Carrying charges on transmission and distribution net plant		39		28		12		5
Bonus depreciation		24		1		23		1
Energy efficiency programs		23		12		21		11
Gas line losses		21		—		21		—
New York State tax refund		20		30		20		30
Gain on sale of properties		14		28		14		28
Expenditure prudence proceeding		11		—		11		—
Other		167		131		157		122
Regulatory liabilities – long-term		821		652		706		547
Net unbilled revenue deferrals – current		116		136		115		135
Revenue decoupling mechanism		99		38		99		38
Refundable energy cost – current		38		117		13		91
Deferred derivative gains – current		4		4		3		3
Regulatory liabilities – current		257		295		230		267
Total Regulatory Liabilities	$	1,078	$	947	$	936	$	814

Note C — Short-Term Borrowing

In October 2011, Con Edison and the Utilities entered into a Credit Agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis, and terminated their Amended and Restated Credit Agreement (Prior Credit Agreement) which was to expire in June 2012. Under the Credit Agreement, which expires in October 2016, there is a maximum of $2.25 billion of credit available, with the full amount available to CECONY and $1 billion available to Con Edison, including up to $1.2 billion of letters of credit. The Credit Agreement supports the Companies’ commercial paper programs. The Companies have not borrowed under the Credit Agreement.

The banks’ commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the

20

Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at September 30, 2011 this ratio was 0.48 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding 5 percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings.

At September 30, 2011 and December 31, 2010 Con Edison and CECONY had no commercial paper outstanding.

At September 30, 2011 and December 31, 2010, no loans were outstanding under the Companies’ Credit Agreement or Prior Credit Agreement and $223 million (including $170 million for CECONY) and $197 million (including $145 million for CECONY) of letters of credit were outstanding under the Credit Agreement or Prior Credit Agreement, respectively.

Note D — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic benefit costs for the three and nine months ended September 30, 2011 and 2010 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost – including administrative expenses	$	48		$	42		$	45		$	39
Interest cost on projected benefit obligation		140			139			131			130
Expected return on plan assets		(184	)		(175	)		(174	)		(167	)
Amortization of net actuarial loss		133			106			126			100
Amortization of prior service costs		2			2			—			2
NET PERIODIC BENEFIT COST	$	139		$	114		$	128		$	104
Amortization of regulatory asset		—			—			—			—
TOTAL PERIODIC BENEFIT COST	$	139		$	114		$	128		$	104
Cost capitalized		(45	)		(40	)		(42	)		(36	)
Cost deferred		(11	)		(29	)		(11	)		(29	)
Cost charged to operating expenses	$	83		$	45		$	75		$	39

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost – including administrative expenses	$	142		$	126		$	133		$	117
Interest cost on projected benefit obligation		420			417			393			390
Expected return on plan assets		(550	)		(527	)		(524	)		(501	)
Amortization of net actuarial loss		397			318			376			300
Amortization of prior service costs		6			6			4			6
NET PERIODIC BENEFIT COST	$	415		$	340		$	382		$	312
Amortization of regulatory asset*		1			1			1			1
TOTAL PERIODIC BENEFIT COST	$	416		$	341		$	383		$	313
Cost capitalized		(141	)		(118	)		(131	)		(109	)
Cost deferred		(68	)		(85	)		(70	)		(82	)
Cost charged to operating expenses	$	207		$	138		$	182		$	122

* Relates to increases in CECONY’s pension obligations of $45 million from a 1999 special retirement program.

21

Expected Contributions

The Companies are not required under funding regulations and laws to make any contributions to the pension plan during 2011. The Companies’ policy is to fund their accounting cost to the extent tax deductible. In 2011, Con Edison contributed $533 million to the pension plan (of which $491 million was contributed by CECONY). During the first nine months of 2010, Con Edison contributed $434 million to the pension plan (of which $397 million was contributed by CECONY). During the first nine months of 2011, the Companies funded $11 million for the non-qualified supplemental pension plans.

Note E — Other Postretirement Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic postretirement benefit costs for the three and nine months ended September 30, 2011 and 2010 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost	$	7		$	6		$	5		$	5
Interest cost on accumulated other postretirement benefit obligation		20			23			18			20
Expected return on plan assets		(22	)		(22	)		(21	)		(19	)
Amortization of net actuarial loss		22			23			20			21
Amortization of prior service cost		(3	)		(3	)		(3	)		(4	)
Amortization of transition obligation		1			1			1			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	25		$	28		$	20		$	24
Cost capitalized		(9	)		(10	)		(7	)		(8	)
Cost deferred		3			2			3			1
Cost charged to operating expenses	$	19		$	20		$	16		$	17

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost	$	19		$	18		$	15		$	15
Interest cost on accumulated other postretirement benefit obligation		62			69			54			60
Expected return on plan assets		(66	)		(66	)		(59	)		(57	)
Amortization of net actuarial loss		66			69			60			63
Amortization of prior service cost		(7	)		(9	)		(9	)		(12	)
Amortization of transition obligation		3			3			3			3
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	77		$	84		$	64		$	72
Cost capitalized		(27	)		(30	)		(22	)		(25	)
Cost deferred		12			2			10			(1	)
Cost charged to operating expenses	$	62		$	56		$	52		$	46

Expected Contributions

Con Edison expects to make a contribution of $84 million, including $74 million for CECONY, to the other postretirement benefit plans in 2011. During the first nine months of 2011, Con Edison contributed $35 million to the other postretirement benefit plans (of which $30 million was contributed by CECONY).

Note F — 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

22

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 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, 2011 and December 31, 2010 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Accrued Liabilities:
Manufactured gas plant sites	$	432	$	446	$	314	$	327
Other Superfund Sites		64		66		63		65
Total	$	496	$	512	$	377	$	392
Regulatory assets	$	681	$	695	$	563	$	574

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. Under their current rate agreements, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs. In February 2011, the NYSPSC initiated a proceeding to examine the existing mechanisms pursuant to which utilities recover such costs and possible alternatives.

Environmental remediation costs incurred related to Superfund Sites for the three and nine months ended September 30, 2011 and 2010, were as follows:

	For the Three Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Remediation costs incurred	$	9	$	9	$	9	$	8

	For the Nine Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Remediation costs incurred	$	24	$	32	$	22	$	30

There were no insurance recoveries related to Superfund Sites for the three months ended September 30, 2011 and 2010. Insurance recoveries related to Superfund Sites for the nine months ended September 30, 2011 and 2010 were immaterial.

In 2010, CECONY estimated that for its manufactured gas plant sites, its aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other manufactured gas plant-related environmental contaminants could range up to $1.9 billion. In 2010, O&R estimated that for its manufactured gas plant sites, each of which has been investigated, the aggregate undiscounted potential liability for the remediation of such contaminants could range up to $200 million. 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.

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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. In 2010, CECONY estimated that its aggregate undiscounted potential liability for these suits and additional suits that may be brought over the next 15 years is $10 million. The estimate was based upon a combination of modeling, historical data analysis and risk factor assessment. Actual experience may be materially different. 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 agreements, 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, 2011 and December 31, 2010 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Accrued liability – asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets – asbestos suits	$	10	$	10	$	10	$	10
Accrued liability – workers’ compensation	$	99	$	106	$	94	$	101
Regulatory assets – workers’ compensation	$	25	$	31	$	24	$	31

Note G — 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 100 suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for personal injury, property damage and business interruption. The company has not accrued a liability for the suits. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover most of the company’s costs, which the company is unable to estimate, but which could be substantial, to satisfy its liability to others in connection with the incident.

Investigations of Vendor Payments

In January 2009, CECONY commenced an internal investigation relating to the arrests of certain employees and retired employees (all of whom have since been convicted) for accepting kickbacks from contractors that performed construction work for the company. The company has retained a law firm, which has retained an accounting firm, to assist in the company’s investigation. The company has provided information to governmental authorities, which consider the company to be a victim of unlawful conduct, in connection with their investigation of the arrested employees and contractors. The company has terminated its employment of the arrested employees and its contracts with the contractors. In February 2009, the NYSPSC commenced a proceeding that, among other things, will examine the prudence of certain of the company’s expenditures relating to the arrests and consider whether additional expenditures should also be examined (see “Other Regulatory Matters” in Note B).

CECONY is also investigating the September 2010 arrest of a retired employee (who has since pleaded guilty to participating in a bribery scheme in which the employee received payments from two companies that supplied materials to the company) and the January 2011 arrest of an employee (for accepting kickbacks from an engineering firm that performed work for the

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company). CECONY has provided information to governmental authorities in connection with their ongoing investigations of these matters.

The company, based upon its evaluation of its internal controls for 2010 and previous years, believes that the controls were effective to provide reasonable assurance that its financial statements have been fairly presented, in all material respects, in conformity with generally accepted accounting principles. Because the company’s investigations are ongoing, the company is unable to predict the impact of any of the employees’ unlawful conduct on the company’s internal controls, business, results of operations or financial position.

Lease In/Lease Out Transactions

In each of 1997 and 1999, Con Edison Development entered into a transaction in which it leased property and then immediately subleased it back to the lessor (termed “Lease In/Lease Out,” or LILO transactions). The transactions respectively involve electric generating and gas distribution facilities in the Netherlands, with a total investment of $259 million. The transactions were financed with $93 million of equity and $166 million of non-recourse, long-term debt secured by the underlying assets. In accordance with the accounting rules for leases, Con Edison is accounting for the two LILO transactions as leveraged leases. Accordingly, the company’s investment in these leases, net of non-recourse debt, is carried as a single amount in Con Edison’s consolidated balance sheet and income is recognized pursuant to a method that incorporates a level rate of return for those years when net investment in the lease is positive, based upon the after-tax cash flows projected at the inception of the leveraged leases. The company’s investment in these leveraged leases was $(52) million at September 30, 2011 and $(41) million at December 31, 2010 and is comprised of a $234 million gross investment less $286 million deferred tax liabilities at September 30, 2011 and $235 million gross investment less $276 million of deferred tax liabilities at December 31, 2010.

On audit of Con Edison’s tax return for 1997, the IRS disallowed the tax losses in connection with the 1997 LILO transaction. In December 2005, Con Edison paid a $0.3 million income tax deficiency asserted by the IRS for the tax year 1997 with respect to the 1997 LILO transaction. In April 2006, the company paid interest of $0.2 million associated with the deficiency and commenced an action in the United States Court of Federal Claims, entitled Consolidated Edison Company of New York, Inc. v. United States, to obtain a refund of this tax payment and interest. A trial was completed in November 2007. In October 2009, the court issued a decision in favor of the company concluding that the 1997 LILO transaction was, in substance, a true lease that possessed economic substance, the loans relating to the lease constituted bona fide indebtedness, and the deductions for the 1997 LILO transactions claimed by the company in its 1997 federal income tax return are allowable. The IRS is entitled to appeal the decision.

In connection with its audit of Con Edison’s federal income tax returns for 1998 through 2007, the IRS disallowed $416 million of net tax deductions taken with respect to both of the LILO transactions for the tax years. Con Edison is pursuing administrative appeals of these audit level disallowances. In connection with its audit of Con Edison’s federal income tax returns for 2010, 2009 and 2008, the IRS has disallowed $40 million, $41 million and $42 million, respectively, of net tax deductions taken with respect to both of the LILO transactions. When these audit level disallowances become appealable, Con Edison intends to file an appeal of the disallowances.

Con Edison believes that its LILO transactions have been correctly reported, and has not recorded any reserve with respect to the disallowance of tax losses, or related interest, in connection with its LILO transactions. Con Edison’s estimated tax savings, reflected in its financial statements, from the two LILO transactions through September 30, 2011, in the aggregate, was $232 million. If Con Edison were required to repay all or a portion of these amounts, it would also be required to pay interest of up to $86 million net of tax at September 30, 2011.

Pursuant to the accounting rules for leveraged lease transactions, the expected timing of income tax cash flows generated by Con Edison’s LILO transactions are required to be reviewed at least annually. If the

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expected timing of the cash flows is revised, the rate of return and the allocation of income would be recalculated from the inception of the LILO transactions, and the company would be required to recalculate the accounting effect of the LILO transactions, which would result in a charge to earnings that could have a material adverse effect on the company’s results of operations.

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 $862 million and $859 million at September 30, 2011 and December 31, 2010, respectively.

A summary, by type and term, of Con Edison’s total guarantees at September 30, 2011 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	652	$	3	$	153	$	808
Intra-company guarantees		15		—		1		16
Other guarantees		25		13		—		38
TOTAL	$	692	$	16	$	154	$	862

Energy Transactions — Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in gas, pipeline capacity, transportation, oil, electricity 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.

Intra-company Guarantees — Con Edison guarantees electricity sales made by Con Edison Energy and Con Edison Solutions to O&R and CECONY.

Other Guarantees — Con Edison, also guarantees the following:

• $13 million relates to a guarantee issued by Con Edison to CECONY covering a former Con Edison subsidiary’s lease payments to use CECONY’s conduit system in accordance with a tariff approved by the NYSPSC and a guarantee issued by Con Edison to a landlord to guarantee the former subsidiary’s obligations under a building lease. The former subsidiary is obligated to reimburse Con Edison for any payments made under these guarantees. This obligation is fully secured by letters of credit;

• $25 million for guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects performed by Con Edison Solutions; and

• Con Edison, on behalf of Con Edison Solutions, as a retail electric provider, issued a guarantee to the Public Utility Commission of Texas with no specified limitation on the amount guaranteed, covering the payment of all obligations of a retail electric provider. Con Edison’s estimate of the maximum potential obligation is $5 million as of September 30, 2011.

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Note H — Financial Information by Business Segment

The financial data for the business segments are as follows:

	For the Three Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2011			2010			2011			2010			2011		2010		2011			2010
CECONY
Electric	$	2,644		$	2,570		$	3		$	3		$	166	$	156	$	758		$	715
Gas		197			204			1			1			28		26		(23	)		(16	)
Steam		76			91			20			18			15		16		(33	)		(33	)
Consolidation adjustments		—			—			(24	)		(22	)		—		—		—			—
Total CECONY	$	2,917		$	2,865		$	—		$	—		$	209	$	198	$	702		$	666
O&R
Electric	$	217		$	245		$	—		$	—		$	9	$	8	$	44		$	52
Gas		24			25			—			—			3		3		(6	)		(4	)
Total O&R	$	241		$	270		$	—		$	—		$	12	$	11	$	38		$	48
Competitive energy businesses	$	472		$	584		$	3		$	2		$	1	$	2	$	16		$	(8	)
Other*		(1	)		(12	)		(3	)		(2	)		—		—		—			(1	)
Total Con Edison	$	3,629		$	3,707		$	—		$	—		$	222	$	211	$	756		$	705

* Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

	For the Nine Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2011			2010			2011			2010			2011		2010		2011			2010
CECONY
Electric	$	6,378		$	6,402		$	9		$	9		$	489	$	464	$	1,326		$	1,228
Gas		1,156			1,126			4			4			82		76		212			243
Steam		508			487			59			55			47		46		81			41
Consolidation adjustments		—			—			(72	)		(68	)		—		—		—			—
Total CECONY	$	8,042		$	8,015		$	—		$	—		$	618	$	586	$	1,619		$	1,512
O&R
Electric	$	507		$	559		$	—		$	—		$	26	$	24	$	69		$	71
Gas		153			150			—			—			10		9		22			20
Total O&R	$	660		$	709		$	—		$	—		$	36	$	33	$	91		$	91
Competitive energy businesses	$	1,286		$	1,491		$	9		$	6		$	5	$	7	$	75		$	25
Other*		(16	)		(30	)		(9	)		(6	)		—		—		(2	)		(1	)
Total Con Edison	$	9,972		$	10,185		$	—		$	—		$	659	$	626	$	1,781		$	1,627

* Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

Note I — Derivative Instruments and Hedging Activities

Under the accounting rules for derivatives and hedging, derivatives are recognized on the balance sheet at fair value, unless an exception is available under the accounting rules. Certain qualifying derivative contracts have been designated as normal purchases or normal sales contracts. These contracts are not reported at fair value under the accounting rules.

Energy Price Hedging

Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, and steam by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. The fair values of these hedges at September 30, 2011 and December 31, 2010 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Fair value of net derivative assets/(liabilities) – gross	$	(115	)	$	(261	)	$	(62	)	$	(156	)
Impact of netting of cash collateral		73			176			41			104
Fair value of net derivative assets/(liabilities) – net	$	(42	)	$	(85	)	$	(21	)	$	(52	)

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Credit Exposure

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. 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.

At September 30, 2011, Con Edison and CECONY had $120 million and $24 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $60 million with investment-grade counterparties, $44 million with commodity exchange brokers, $15 million with independent system operators and $1 million with non-investment grade counterparties. CECONY’s entire net credit exposure was with commodity exchange brokers.

Economic Hedges

The Companies enter into certain derivative instruments that do not qualify or are not designated as hedges under the accounting rules for derivatives and hedging. However, management believes these instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

The fair values of the Companies’ commodity derivatives at September 30, 2011 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets	$	112		$	41
Long-term	Other deferred charges and non-current assets		36			23
Total derivative assets		$	148		$	64
Impact of netting			(68	)		(25	)
Net derivative assets		$	80		$	39
Derivative Liabilities
Current	Fair value of derivative liabilities	$	209		$	95
Long-term	Fair value of derivative liabilities		54			31
Total derivative liabilities		$	263		$	126
Impact of netting			(141	)		(66	)
Net derivative liabilities		$	122		$	60

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

The fair values of the Companies’ commodity derivatives at December 31, 2010 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets	$	184		$	29
Long-term	Other deferred charges and non-current assets		51			19
Total derivative assets		$	235		$	48
Impact of netting			(129	)		—
Net derivative assets		$	106		$	48
Derivative Liabilities
Current	Fair value of derivative liabilities	$	385		$	148
Long-term	Fair value of derivative liabilities		111			56
Total derivative liabilities		$	496		$	204
Impact of netting			(305	)		(104	)
Net derivative liabilities		$	191		$	100

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

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The Utilities generally recover all of their prudently incurred fuel, purchased power and gas cost, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility commissions. 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 earnings in the reporting period in which they occur.

The following tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2011:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the three months ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(2	)	$	(1	)
Long-term	Regulatory liabilities		1			1
Total deferred gains		$	(1	)	$	—
Current	Deferred derivative losses	$	12		$	7
Current	Recoverable energy costs		(75	)		(53	)
Long-term	Regulatory assets		10			6
Total deferred losses		$	(53	)	$	(40	)
Net deferred losses		$	(54	)	$	(40	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	29	(b)	$	—
	Gas purchased for resale		6			—
	Non-utility revenue		5	(b)		—
Total pre-tax gain/(loss) recognized in income		$	40		$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the three months ended September 30, 2011 Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss) of $(10) million and $(1) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the nine months ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	—		$	—
Long-term	Regulatory liabilities		3			3
Total deferred gains		$	3		$	3
Current	Deferred derivative losses	$	80		$	61
Current	Recoverable energy costs		(177	)		(134	)
Long-term	Regulatory assets		38			27
Total deferred losses		$	(59	)	$	(47	)
Net deferred losses		$	(56	)	$	(44	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	81	(b)	$	—
	Gas purchased for resale		17			—
	Non-utility revenue		22	(b)		—
Total pre-tax gain/(loss) recognized in income		$	120		$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

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(b) For the nine months ended September 30, 2011, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss)/gain of $(35) million and $59 million, respectively.

The following tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2010:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended September 30, 2010
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(3	)	$	(3	)
Total deferred losses		$	(3	)	$	(3	)
Current	Other current assets	$	(61	)	$	(54	)
Current	Recoverable energy costs		(70	)		(63	)
Long term	Regulatory assets		4			7
Total deferred losses		$	(127	)	$	(110	)
Net deferred losses		$	(130	)	$	(113	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(26	)(b)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		4	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(23	)	$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the three months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(3)million and $(34) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 2010
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(8	)	$	(8	)
Total deferred losses		$	(8	)	$	(8	)
Current	Other current assets	$	(127	)	$	(114	)
Current	Recoverable energy costs	$	(205	)	$	(172	)
Long term	Regulatory assets	$	(19	)	$	(11	)
Total deferred losses		$	(351	)	$	(297	)
Net deferred losses		$	(359	)	$	(305	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(132	)(b)	$	—
	Gas purchased for resale		(7	)		—
	Non-utility revenue		21	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(118	)	$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the nine months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(1) million and $(34) million, respectively.

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As of September 30, 2011, Con Edison had 1,565 contracts, including 612 CECONY contracts, which were considered to be derivatives under the accounting rules for derivatives and hedging (excluding qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts). The following table presents the number of contracts by commodity type:

	Electric Derivatives								Gas Derivatives
	Number of Energy Contracts (a)		MWHs (b)		Number of Capacity Contracts (a)		MWs (b)		Number of Contracts (a)		Dths (b)		Total Number Of Contracts (a)
Con Edison		810		16,479,730		73		8,201		682		98,382,500		1,565
CECONY		146		4,025,375		—		—		466		90,710,000		612

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) Volumes are reported net of long and short positions.

The Companies also enter into electric congestion and gas basis swap contracts to hedge the congestion and transportation charges which are associated with electric and gas contracts and hedged volumes.

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 the Companies to provide collateral on derivative instruments in net liability positions. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the Companies’ credit ratings.

The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position and collateral posted at September 30, 2011, 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 were:

(Millions of Dollars)	Con Edison (a)			CECONY (a)
Aggregate fair value – net liabilities	$	128		$	70
Collateral posted	$	34	(b)	$	29	(b)
Additional collateral (c) (downgrade one level from current ratings (d))	$	11		$	9
Additional collateral (c) (downgrade to below investment grade from current ratings (d))	$	143	(e)	$	54	(e)

(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 Con Edison’s competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post collateral, which at September 30, 2011, would have amounted to an estimated $146 million for Con Edison. 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) Across the Utilities’ energy derivative positions, credit limits for the same counterparties are generally integrated. At September 30, 2011, the Utilities posted combined collateral of $34 million, including an estimated $5 million attributable to O&R.

(c) 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 of setoff.

(d) The current ratings are Moody’s, S&P and Fitch long-term credit rating of, as applicable, Con Edison (Baa1/BBB+/BBB+), CECONY (A3/A-/A-) or O&R (Baa1/A-/A-). Credit ratings assigned by rating agencies are expressions of opinions that are subject to revision or withdrawal at any time by the assigning rating agency.

(e) Derivative instruments that are net assets have been excluded from the table. At September 30, 2011, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of an estimated $16 million.

Interest Rate Swap

O&R has an interest rate swap pursuant to which it pays a fixed-rate of 6.09 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at September 30, 2011 was an unrealized loss of $9 million, which has been included in Con Edison’s consolidated balance sheet as a noncurrent liability/fair value of derivative liabilities and a regulatory asset. The increase in the fair value of the swap for the three and nine months ended

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September 30, 2011 was not material. In the event O&R’s credit rating was downgraded to BBB- or lower by S&P or Baa3 or lower by Moody’s, the swap counterparty could elect to terminate the agreement and, if it did so, the parties would then be required to settle the transaction.

Note J — 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.

The valuation technique used by the Companies with regard to commodity derivatives and other assets that fall into either Level 2 or Level 3 is the market approach, which uses prices and other relevant information generated by market transactions involving identical or comparable assets and liabilities. The valuation technique used by the Companies with regard to the interest rate contract that falls into Level 3 is the income approach which uses valuation techniques to convert future income stream amounts to a single amount in present value terms.

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Assets and liabilities measured at fair value on a recurring basis as of September 30, 2011 are summarized as follows:

	Level 1				Level 2						Level 3						Netting Adjustments (4)						Total
(Millions of Dollars)	Con Edison		CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity	$	2	$	—	$	52		$	28		$	69		$	17		$	(44	)	$	(6	)	$	79		$	39
Transfer in (5) (6)		1		1		—			—			—			—			—			—			1			1
Transfer out (5) (6)		—		—		(1	)		(1	)		—			—			—			—			(1	)		(1	)
Commodity (1)		3		1		51			27			69			17			(44	)		(6	)		79			39
Other assets (3)		75		75		—			—			100			91			—			—			175			166
Total	$	78	$	76	$	51		$	27		$	169		$	108		$	(44	)	$	(6	)	$	254		$	205
Derivative liabilities:
Commodity	$	10	$	5	$	130		$	91		$	98		$	11		$	(117	)	$	(47	)	$	121		$	60
Transfer in (5) (7)		—		—		23			8			1			1			—			—			24			9
Transfer out (5) (7)		—		—		(1	)		(1	)		(23	)		(8	)		—			—			(24	)		(9	)
Commodity (1)	$	10	$	5	$	152		$	98		$	76		$	4		$	(117	)	$	(47	)	$	121		$	60
Interest rate contract (2)		—		—		—			—			9			—			—			—			9			—
Total	$	10	$	5	$	152		$	98		$	85		$	4		$	(117	)	$	(47	)	$	130		$	60

(1) A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

(2) See Note I.

(3) Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

(4) 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.

(5) The Companies’ policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

(6) Transferred from Level 2 to Level 1 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

(7) Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2010 to less than one year as of September 30, 2011.

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2010 are summarized as follows:

	Level 1				Level 2						Level 3						Netting Adjustments (4)						Total
(Millions of Dollars)	Con Edison		CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity (1)	$	2	$	1	$	72		$	21		$	144		$	13		$	(112	)	$	13		$	106		$	48
Other assets (3)		65		64		—			—			101			92			—			—			166			156
Total	$	67	$	65	$	72		$	21		$	245		$	105		$	(112	)	$	13		$	272		$	204
Derivative liabilities:
Commodity	$	4	$	2	$	270		$	177		$	205		$	12		$	(288	)	$	(91	)	$	191		$	100
Transfer in (5) (6) (7)		—		—		(36	)		(36	)		(9	)		(9	)		—			—			(45	)		(45	)
Transfer out (5) (6) (7)		—		—		9			9			36			36			—			—			45			45
Commodity (1)	$	4	$	2	$	243		$	150		$	232		$	39		$	(288	)	$	(91	)	$	191		$	100
Interest rate contract (2)		—		—		—			—			10			—			—			—			10			—
Total	$	4	$	2	$	243		$	150		$	242		$	39		$	(288	)	$	(91	)	$	201		$	100

(1) A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

(2) See Note I.

(3) Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

(4) 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.

(5) The Companies’ policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

(6) Transferred from Level 2 to Level 3 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

(7) Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2009 to less than one year as of December 31, 2010.

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The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2011 and classified as Level 3 in the fair value hierarchy below.

	For the Three Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity	$	(25	)	$	(27	)	$	9		$	8	$	—	$	—	$	4	$	24	$	(7	)
Interest rate contract		(10	)		(1	)		1			—		—		—		1		—		(9	)
Other assets (1)		106			(3	)		(3	)		—		—		—		—		—		100
Total	$	71		$	(31	)	$	7		$	8	$	—	$	—	$	5	$	24	$	84
CECONY
Derivatives:
Commodity	$	—		$	(8	)	$	1		$	8	$	—	$		$	3	$	9	$	13
Other assets (1)		96			(3	)		(2	)		—		—				—		—		91
Total	$	96		$	(11	)	$	(1	)	$	8	$	—	$		$	3	$	9	$	104

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

	For the Nine Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	(5	)	$	54		$	22	$	—	$	—	$	(19	)	$	29	$	(7	)
Interest rate contract		(10	)		(3	)		1			—		—		—		3			—		(9	)
Other assets (1)		101			—			(1	)		—		—		—		—			—		100
Total	$	3		$	(8	)	$	54		$	22	$	—	$	—	$	(16	)	$	29	$	84
CECONY
Derivatives:
Commodity	$	(26	)	$	(11	)	$	22		$	18	$	—	$	—	$	(4	)	$	14	$	13
Other assets (1)		92			—			(1	)		—		—		—		—			—		91
Total	$	66		$	(11	)	$	21		$	18	$	—	$	—	$	(4	)	$	14	$	104

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

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The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2010 and classified as Level 3 in the fair value hierarchy below.

	For the Three Months Ended September 30, 2010
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2010			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of September 30, 2010
Con Edison
Derivatives:
Commodity	$	(101	)	$	(34	)	$	(12	)	$	1	$	—	$	—	$	4	$	(2	)	$	(144	)
Interest rate contract		(12	)		—			—			—		—		—		—		—			(12	)
Other assets (1)		94			—			2			—		—		—		—		—			96
Total	$	(19	)	$	(34	)	$	(10	)	$	1	$	—	$	—	$	4	$	(2	)	$	(60	)
CECONY
Derivatives:
Commodity	$	(30	)	$	(7	)	$	(3	)	$	1	$	—	$	—	$	4	$	(2	)	$	(37	)
Other assets (1)		85			—			2			—		—		—		—		—			87
Total	$	55		$	(7	)	$	(1	)	$	1	$	—	$	—	$	4	$	(2	)	$	50

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

	For Nine Months Ended September 30, 2010
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2010			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2010
Con Edison
Derivatives:
Commodity	$	(59	)	$	(68	)	$	(56	)	$	2	$	—	$	—	$	16		$	21	$	(144	)
Interest rate contract		(11	)		(2	)		(1	)		—		—		—		2			—		(12	)
Other assets (1)		92			—			4			—		—		—		—			—		96
Total	$	22		$	(70	)	$	(53	)	$	2	$	—	$	—	$	18		$	21	$	(60	)
CECONY
Derivatives:
Commodity	$	(5	)	$	(14	)	$	(37	)	$	—	$	—	$	—	$	(2	)	$	21	$	(37	)
Other assets (1)		83			—			4			—		—		—		—			—		87
Total	$	78		$	(14	)	$	(33	)	$	—	$	—	$	—	$	(2	)	$	21	$	(50	)

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

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 commissions. 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 ($1 million gain and $14 million gain) and purchased power costs ($13 million loss and $33 million loss) on the consolidated income statement for the three months ended September 30, 2011 and 2010, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($1 million loss and $47 million gain) and purchased power costs ($26 million gain and $73 million loss) on the consolidated income statement for the nine months ended September 30, 2011 and 2010, respectively. The

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change in fair value relating to Level 3 commodity derivative assets held at September 30, 2011 and 2010 is included in non-utility revenues ($10 million loss and $3 million loss), and purchased power costs ($5 million loss and $22 million loss) on the consolidated income statement for the three months ended September 30, 2011 and 2010, respectively. For the nine months ended September 30, 2011 and 2010, the change in fair value relating to Level 3 commodity derivative assets and liabilities included in non-utility revenues ($35 million loss and $2 million loss) and purchased power costs ($31 million gain and $29 million loss) on the consolidated income statement.

The accounting rules for fair value measurements and disclosures require consideration of the impact of non-performance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2011, the Companies determined that non-performance risk would not have a material impact on their financial position or results of operations. To assess non-performance risk, the Companies considered information such as collateral requirements, master netting arrangements, letters of credit and parent company guarantees, and applied a market-based method by using the counterparty’s (for an asset) or the Companies’ (for a liability) credit default swaps rates.

Note K — New Financial Accounting Standards

In May 2011, the Financial Accounting Standards Board (FASB) issued amendments to the guidance for fair value measurement through Accounting Standards Update (ASU) No. 2011-04, “Fair Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs.” The amendments expand Accounting Standards Codification 820’s existing disclosure requirements for fair value measurements and makes other amendments. Many of these amendments were made to eliminate unnecessary wording differences between U.S. generally accepted accounting principles and International Financial Reporting Standards. For public entities, the amendments are effective prospectively during interim and annual periods beginning after December 15, 2011. The application of this guidance is not expected to have a material impact on the companies’ financial position, results of operations and liquidity.

In June 2011, the FASB issued new guidance for presentation of comprehensive income through ASU No. 2011-05, “Comprehensive Income (Topic 220): Presentation of Comprehensive Income.” The amendments require that the comprehensive income be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. In the two-statement approach, the first statement should present total net income and its components followed consecutively by a second statement that should present total other comprehensive income, the components of other comprehensive income, and the total of comprehensive income. The amendments in this update are applicable retrospectively for public entities effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. Early adoption is permitted. The application of this guidance does not have a material impact on the companies’ financial position, results of operations and liquidity.

In September 2011, the FASB issued amendments to the guidance for goodwill impairment testing through ASU No. 2011-08, “Intangibles-Goodwill and Other (Topic 350): Testing Goodwill for Impairment.” The amendments provide guidance that exempts an entity from calculating the fair value of a reporting unit, if on an initial assessment of qualitative factors it is more likely than not that the fair value of a reporting unit is greater than its carrying amount. For public entities, the amendments are effective for interim and annual goodwill tests performed for years beginning after December 15, 2011. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations or liquidity.

In September 2011, the FASB issued amendments to guidance for disclosures related to retirement benefits

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through ASU No. 2011-09, “Compensation—Retirement Benefits—Multiemployer Plans (Subtopic 715-80): Disclosures about an Employer’s Participation in a Multiemployer Plan.” The amendment provides guidance that requires employers to provide additional separate disclosures for multiemployer pension plans and multiemployer other postretirement benefit plans about the commitments an employer has made to a multiemployer plan and the potential future cash flow implication of participation in such a plan. For public entities, the amendments are effective for interim and annual periods ending after December 15, 2011. The application of this guidance is not expected to have a material impact on the companies’ financial position, results of operations or liquidity.

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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) and should be read in conjunction with the financial statements and the notes thereto. 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 MD&A about CECONY applies to Con Edison.

This MD&A should be read in conjunction with the Third Quarter Financial Statements and the notes thereto and the MD&A in Item 7 of the Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2010 (File Nos. 1-14514 and 1-1217, the Form 10-K) and the MD&A in Part 1, Item 2 of the Companies’ combined Quarterly Report on Form 10-Q for the quarterly periods ended March 31, 2011 and June 30, 2011 (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 which owns all of the outstanding common stock of CECONY, Orange and Rockland Utilities, Inc. (O&R) and the competitive energy businesses. As used in this report, the term the “Utilities” refers to CECONY and O&R.

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 sell electricity to wholesale and retail customers, provide certain energy-related services, and participate in energy infrastructure projects. Con Edison is evaluating additional opportunities to invest in electric and gas-related businesses.

Con Edison’s strategy is to provide reliable energy services, maintain public and employee safety, promote energy efficiency, and develop cost-effective ways of performing its business. Con Edison seeks to be a responsible steward of the environment and enhance its relationships with customers, regulators and members of the communities it serves.

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CECONY

Electric

CECONY provides electric service to approximately 3.3 million customers in all of New York City (except part of Queens) and most of Westchester County, an approximately 660 square mile service area with a population of more than nine million.

Gas

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

Steam

CECONY operates the largest steam distribution system in the United States by producing and delivering more than 23,000 MMlbs of steam annually to approximately 1,760 customers in parts of Manhattan.

O&R

Electric

O&R and its utility subsidiaries, Rockland Electric Company (RECO) and Pike County Light & Power Company (Pike) (together referred to herein as O&R) provide electric service to approximately 0.3 million customers in southeastern New York and in adjacent areas of northern New Jersey and northeastern Pennsylvania, an approximately 1,350 square mile service area.

Gas

O&R delivers gas to over 0.1 million customers in southeastern New York and adjacent areas of northeastern Pennsylvania.

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 include the sales and related hedging of electricity to wholesale and retail customers, sales of certain energy-related products and services, and participation in energy infrastructure projects. At September 30, 2011, Con Edison’s equity investment in its competitive energy businesses was $374 million and their assets amounted to $854 million.

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

	Three Months Ended September 30, 2011									Nine Months Ended September 30, 2011										At September 30, 2011
(Millions of Dollars, except percentages)	Operating Revenues					Net Income for Common Stock				Operating Revenues					Net Income for Common Stock					Assets
CECONY	$	2,917		80	%	$	353	92	%	$	8,042		81	%	$	779		91	%	$	32,654	90	%
O&R		241		7	%		20	6	%		660		6	%		44		5	%		2,296	6	%
Total Utilities		3,158		87	%		373	98	%		8,702		87	%		823		96	%		34,950	96	%
Con Edison Solutions (a)		416		11	%		5	1	%		1,111		11	%		38		4	%		344	1	%
Con Edison Energy (a)		57		2	%		5	1	%		179		2	%		7		1	%		83	—	%
Con Edison Development		2		—	%		—	—	%		5		—	%		1		—	%		468	1	%
Other (b)		(4	)	—	%		—	—	%		(25	)	—	%		(9	)	(1	)%		690	2	%
Total Con Edison	$	3,629		100	%	$	383	100	%	$	9,972		100	%	$	860		100	%	$	36,535	100	%

(a) Net income from the competitive energy businesses for the three and nine months ended September 30, 2011 includes $(7) million and $14 million, respectively, of net after-tax mark-to-market (losses)/gains (Con Edison Solutions, $(8) million and $6 million and Con Edison Energy, $1 million and $8 million).

(b) Represents inter-company and parent company accounting. See “Results of Operations,” below.

Con Edison’s net income for common stock for the three months ended September 30, 2011 was $383 million or $1.31 a share ($1.30 on a diluted basis) compared with earnings of $350 million or $1.24 a share ($1.23 on a diluted basis) for the three months ended September 30, 2010. Net income for common stock for the nine months ended September 30, 2011 was $860 million or $2.94 a share ($2.92 on a diluted basis) compared with earnings of $759 million or $2.69 a share ($2.68 on a diluted basis) for the nine months ended September 30, 2010. See “Results of Operations – Summary,” below. For segment financial information, see Note H to the Third Quarter Financial Statements and “Results of Operations,” below.

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Results of Operations — Summary

Net income for common stock for the three and nine months ended September 30, 2011 and 2010 was as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
(Millions of Dollars)	2011		2010			2011			2010
CECONY	$	353	$	332		$	779		$	709
O&R		20		25			44			42
Competitive energy businesses (a)		10		(3	)		46			18
Other (b)		—		(4	)		(9	)		(10	)
Con Edison	$	383	$	350		$	860		$	759

(a) Includes $(7) million and $(22) million of net after-tax mark-to-market losses for the three months ended September 30, 2011 and 2010, respectively. Includes $14 million and $(21) million of net after-tax mark-to-market gains/(losses) for the nine months ended September 30, 2011 and 2010, respectively.

(b) Consists of inter-company and parent company accounting.

The Companies’ results of operations for the three and nine months ended September 30, 2011, as compared with the 2010 period, reflect changes in the Utilities’ rate plans. These rate plans provide for additional revenues to cover expected increases in certain operations and maintenance expenses, and depreciation and property taxes. The results of operations include the operating results of the competitive energy businesses, including net mark-to-market effects.

Operations and maintenance expenses were higher in the three and nine months ended September 30, 2011 compared with the 2010 periods reflecting higher costs for pension and other postretirement benefits and employee health insurance, offset in part by savings from cost control efforts in the 2011 periods. Depreciation and property taxes were higher in the 2011 periods reflecting primarily higher utility plant balances.

The following table presents the estimated effect on earnings per share and net income for common stock for the three and nine months ended September 30, 2011 as compared with the 2010 periods, resulting from these and other major factors:

	Three Months Variation						Nine Months Variation
	Earnings per Share			Net Income for Common Stock (Millions of Dollars)			Earnings per Share			Net Income for Common Stock (Millions of Dollars)
CECONY
Rate plans, primarily to recover increases in certain costs	$	0.25		$	72		$	0.69		$	192
Operations and maintenance expense		(0.09	)		(27	)		(0.15	)		(44	)
Depreciation and property taxes		(0.08	)		(23	)		(0.24	)		(69	)
Other (includes dilutive effect of new stock issuances)		(0.04	)		(1	)		(0.15	)		(9	)
Total CECONY		0.04			21			0.15			70
O&R		(0.02	)		(5	)		—			1
Competitive energy businesses
Earnings excluding net mark-to-market effects		(0.03	)		(2	)		(0.03	)		(7	)
Net mark-to-market effects		0.06			15			0.13			35
Total competitive energy businesses		0.03			13			0.10			28
Other, including parent company expenses		0.02			4			—			2
Total	$	0.07		$	33		$	0.25		$	101

See “Results of Operations” below for further discussion and analysis of results of operations.

Risk Factors

The Companies’ businesses are influenced by many factors that are difficult to predict, and that involve uncertainties that may materially affect actual operating results, cash flows and financial condition. See “Risk Factors” in Item 1A of this report.

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Application of Critical Accounting Policies

The Companies’ financial statements reflect the application of their accounting policies, which conform to accounting principles generally accepted in the United States of America. The Companies’ critical accounting policies include industry-specific accounting applicable to regulated public utilities and accounting for pensions and other postretirement benefits, contingencies, long-lived assets, derivative instruments, goodwill and leases. At September 30, 2011, there were no material changes in the Companies’ critical accounting policies compared with those discussed under “Application of Critical Accounting Policies” in Item 7 of the Form 10-K.

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, 2011 and 2010 are summarized as follows:

	Con Edison									CECONY
(Millions of Dollars)	2011			2010			Variance			2011			2010			Variance
Operating activities	$	2,161		$	974		$	1,187		$	1,960		$	938		$	1,022
Investing activities		(1,611	)		(1,566	)		(45	)		(1,450	)		(1,461	)		11
Financing activities		(490	)		530			(1,020	)		(518	)		427			(945	)
Net change		60			(62	)		122			(8	)		(96	)		88
Balance at beginning of period		338			260			78			78			131			(53	)
Balance at end of period	$	398		$	198		$	200		$	70		$	35		$	35

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 dependent primarily on 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 CECONY’s electric and gas rate plans and O&R’s 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 not net income. The prices at which the Utilities provide energy to their customers are determined in accordance with their rate agreements. 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 agreements.

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 include depreciation, deferred income tax expense and net derivative gains or losses. Non-cash charges or credits may also be accrued under the revenue decoupling and cost reconciliation mechanisms in the Utilities’ electric and gas rate plans in New York.

Net cash flows from operating activities for the nine months ended September 30, 2011 for Con Edison and CECONY were $1,187 million and $1,022 million higher, respectively, than in the 2010 period. The increases in net cash flows reflect primarily lower estimated income tax payments and refunds received in 2011 ($416 million for Con Edison and $366 million for CECONY), lower cash collateral paid to brokers and counterparties in 2011 generally reflecting smaller decreases in hedged volume and in commodity prices for derivative transactions ($224 million for Con Edison and $119 million for CECONY) and recoveries received in 2011 for costs incurred relating to the World Trade Center attack ($150 million), offset in part by increased pension contributions in 2011 ($85 million for Con Edison and $80 million for CECONY).

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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 were $45 million higher for Con Edison and $11 million lower for CECONY, in the nine months ended September 30, 2011 compared with the 2010 period. The increase for Con Edison reflects primarily the net investment for the Pilesgrove solar project and higher construction expenditures at Con Edison Development.

Cash Flows from Financing Activities

Net cash flows from financing activities for Con Edison and CECONY decreased $1,020 million and $945 million, respectively, in the nine months ended September 30, 2011 compared with the 2010 period, primarily due to higher net cash flows from operating activities in the 2011 period.

Cash flows from financing activities for the nine months ended September 30, 2011 and 2010 also reflect the issuance of Con Edison common shares through its dividend reinvestment and employee stock plans (2011: 1.2 million shares for $41 million, 2010: 2.7 million shares for $78 million). In addition, as a result of the stock plan issuances, cash used to pay common stock dividends was reduced by $7 million and $36 million in the 2011 and 2010 periods, respectively. The number of shares issued through, and cash flows relating to, the plans in 2011, as compared with 2010, reflect the purchase in 2011 of shares in open-market transactions in connection with the plans.

The Companies had no issuances of long-term debt during the nine months ended September 30, 2011. Net cash flows from financing activities during the nine months ended September 30, 2010 also reflect the following CECONY transactions:

• Issued $350 million 4.45 percent 10-year debentures and $350 million 5.70 percent 30-year debentures; and

• Redeemed at maturity $325 million 8.125 percent 10-year debentures and $300 million 7.50 percent 10-year debentures.

Con Edison’s net cash flows from financing activities for the nine months ended September 30, 2010 also reflect the following O&R transactions:

• Issued $55 million 2.50 percent 5-year debentures and $115 million 5.50 percent 30-year debentures;

• Purchased and cancelled $55 million variable rate, tax-exempt debt which was due in 2014;

• Redeemed in advance of maturity $45 million 7.00 percent 30-year debentures which were due in 2029; and

• Redeemed at maturity $55 million 7.50 percent 10-year debentures.

Cash flows from financing activities of the Companies also reflect commercial paper issuance (included on the consolidated balance sheets as “Notes payable”). The commercial paper amounts outstanding at September 30, 2011 and 2010 and the average daily balances for the nine months ended September 30, 2011 and 2010 for Con Edison and CECONY were as follows:

	2011						2010
(Millions of Dollars, except Weighted Average Yield)	Outstanding at September 30			Daily average			Outstanding at September 30			Daily average
Con Edison	$	—		$	110		$	846		$	429
CECONY	$	—		$	110		$	832		$	408
Weighted average yield		—	%		0.3	%		0.4	%		0.4	%

Common stock issuances and external borrowings are sources of liquidity that could be affected by changes in credit ratings, financial performance and capital market conditions.

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Other Changes in Assets and Liabilities

The following table shows changes in certain assets and liabilities at September 30, 2011, compared with December 31, 2010.

	Con Edison			CECONY
(Millions of Dollars)	2011 vs. 2010 Variance			2011 vs. 2010 Variance
Assets
Regulatory asset – Unrecognized pension and other postretirement costs	$	(602	)	$	(568	)
Accrued unbilled revenue		(154	)		(115	)
Accounts receivable from affiliated companies		—			(249	)
Prepayments		128			303
Liabilities
Pension and retiree benefits		(687	)		(641	)
Regulatory liability – Net unbilled revenue deferrals – current		(20	)		(20	)
Deferred income taxes and investment tax credits		508			468

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

The decrease in the regulatory asset for unrecognized pension and other postretirement benefit costs and the noncurrent liability for pension and retiree benefits reflects the final actuarial valuation of the underfunding of the pension and other retiree benefit plans as measured at December 31, 2010, in accordance with the accounting rules for pensions. The decrease in the regulatory asset also reflects the current year amortization of accounting costs. The decrease in the noncurrent liability for pension and retiree benefits also reflects the contributions to the plans made by the Utilities in 2011. See Notes D and E to the Third Quarter Financial Statements.

Accrued Unbilled Revenues and Regulatory Liability for Net Unbilled Revenues

The decrease in accrued unbilled revenues and the regulatory liability for net unbilled revenues reflects primarily the impact from milder weather in September 2011 as compared with December 2010.

Prepayments and Accounts Receivable from Affiliated Companies

The increase in prepayments for Con Edison and CECONY reflects the portion allocable to the 2011 fourth quarter of CECONY’s July 2011 payment of its New York City semi-annual property taxes ($585 million). For Con Edison, this increase is offset by federal tax refunds received in the 2011 period. For CECONY, these refunds reduced the accounts receivable from affiliated companies.

Deferred Income Taxes and Investment Tax Credits

The increase in the liability for deferred income taxes and investment tax credits reflects the timing of the deduction of expenditures for utility plant which resulted in amounts being collected from customers to pay income taxes in advance of when the income tax payments will be required. See “Cash Flows from Operating Activities,” above.

Capital Requirements and Resources

As of September 30, 2011, there was no material change in the Companies’ capital requirements and resources compared to those disclosed under “Capital Requirements and Resources – Capital Resources” in Item 1 of the Form 10-K, other than as described below.

The Utilities do not anticipate the need to issue any long-term debt to fund their capital requirements for the remainder of 2011 due to tax benefits and refunds received from accelerated deductions for income tax purposes of certain expenditures which resulted in more cash flows from operating activities.

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For each of the Companies, the ratio of earnings to fixed charges (Securities and Exchange Commission basis) for the nine months ended September 30, 2011, the twelve months ended December 31, 2010 and the nine months ended September 30, 2010 was:

	Ratio of Earnings to Fixed Charges
	For the Nine Months Ended September 30, 2011		For the Twelve Months Ended December 31, 2010		For the Nine Months Ended September 30, 2010
Con Edison		3.8		3.3		3.4
CECONY		3.9		3.4		3.6

For each of the Companies, the common equity ratio at September 30, 2011 and December 31, 2010 was:

	Common Equity Ratio (Percent of total capitalization)
	September 30, 2011		December 31, 2010
Con Edison		52.0		50.4
CECONY		51.4		49.9

Contractual Obligations

At September 30, 2011, there were no material changes in the Companies’ aggregate obligation to make payments pursuant to contracts compared to those discussed under “Capital Requirements and Resources – Contractual Obligations” in Item 1 of the Form 10-K. In August 2011, CECONY extended an existing power purchase agreement with Entergy Nuclear Power Marketing, LLC. The contracted output for 2011 and 2012 remains 350 MW and increases to 500 MW for 2013 through 2017.

Electric Power Requirements

At September 30, 2011, there were no material changes in the Companies’ electric power requirements compared to those disclosed under “Electric Operations – Electric Supply” in Item 1 of the Form 10-K. See “Contractual Obligations,” above.

On July 22, 2011, electric peak demand in Con Edison of New York’s service area reached a new record of 13,189 MW, exceeding the previous record of 13,141 MW reached in 2006. Also on that day, electric peak demand in O&R’s service area reached 1,599 MW, its highest level since the 1,617 MW record peak reached in 2006. On the same day, the New York Independent System Operator invoked demand reduction programs for the Utilities’ customers. Without these reduction programs, the actual peak demand in the Utilities’ service areas would have been higher.

Regulatory Matters

As of September 30, 2011, there were no material changes in the Utilities’ rate plans and other regulatory matters affecting the Companies compared with those disclosed under “Utility Regulation” in Item 1 of the Form 10-K and “Rate Agreements” in Note B to the financial statements in Item 8 of the Form 10-K, other than as described in Note B 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. At September 30, 2011, there were no material changes in the Companies’ financial and commodity market risks compared to those discussed under “Financial and Commodity Market Risks” in Item 7 of the Form 10-K, other than as described below and in Note I to the Third Quarter Financial Statements.

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 I to the Third Quarter Financial Statements.

Con Edison estimates that, as of September 30, 2011, a 10 percent decline in market prices would result in a decline in fair value of $81 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $68 million is for CECONY and $13 million is for O&R. Con Edison expects that any such change in fair value would be

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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 risk of their electricity and gas commodity fixed-price purchase and sales commitments, physical forward contracts and commodity derivative instruments. VaR represents the potential change in fair value of instruments or the portfolio due to changes in market factors, for a specified time period and confidence level. These businesses estimate VaR across their electricity and natural gas commodity businesses using a delta-normal variance/covariance model with a 95 percent confidence level. 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 transactions associated with hedges on generating assets and commodity contracts, assuming a one-day holding period, for the nine months ended September 30, 2011 and the year ended December 31, 2010 was as follows:

95% Confidence Level, One-Day Holding Period	September 30, 2011		December 31, 2010
	(Millions of Dollars)
Average for the period	$	1	$	1
High		1		1
Low		—		—

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. 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 and 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 of setoff. See “Credit Exposure” in Note I to the Third Quarter Financial Statements.

Environmental Matters

At September 30, 2011, there were no material changes in the information concerning climate change, environmental sustainability, potential liabilities arising from laws and regulations protecting the environment and other environmental matters compared with those discussed under “Environmental Matters” in Item 1 of the Form 10-K. See Notes F and G to the Third Quarter Financial Statements.

Impact of Inflation

The Companies are affected by the decline in the purchasing power of the dollar caused by inflation. Regulation permits the Utilities to recover through depreciation only the historical cost of their plant assets even though in an inflationary economy the cost to replace the assets upon their retirement will substantially exceed historical costs. The impact is, however, partially offset by the repayment of the Companies’ long-term debt in dollars of lesser value than the dollars originally borrowed.

Material Contingencies

For information concerning potential liabilities arising from the Companies’ material contingencies, see Notes B, F and G to the Third Quarter Financial Statements.

Results of Operations

See “Results of Operations – Summary,” above.

Results of operations reflect, among other things, the Companies’ accounting policies and rate plans that limit the rates the Utilities can charge their customers. Under the revenue decoupling mechanisms currently applicable to CECONY’s electric and gas businesses and O&R’s electric and gas businesses in New York, the Utilities’ delivery revenues generally will not be affected by changes in delivery volumes from levels

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assumed when rates were approved. Revenues for CECONY’s steam business and O&R’s businesses in New Jersey and Pennsylvania are affected by changes in delivery volumes resulting from weather, economic conditions and other factors.

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. Management uses the term “net revenues” (operating revenues less such costs) to identify changes in operating revenues that may affect the Companies’ results of operations. Management believes that, although “net revenues” may not be a measure determined in accordance with accounting principles generally accepted in the United States of America, the measure facilitates the analysis by management and investors of the Companies’ results of operations.

Con Edison’s principal business segments are CECONY’s regulated electric, gas and steam utility activities, O&R’s regulated electric and gas utility activities and Con Edison’s competitive energy businesses. 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, 2011 and 2010 follows. For additional business segment financial information, see Note H to the Third Quarter Financial Statements.

Three Months Ended September 30, 2011 Compared with Three Months Ended September 30, 2010

The Companies’ results of operations in 2011 compared with 2010 were:

	CECONY						O&R						Competitive Energy Businesses and 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
Operating revenues	$	52			1.8	%	$	(29	)		(10.7	)%	$	(101	)		(17.7	)%	$	(78	)		(2.1	)%
Purchased power		(28	)		(3.7	)		(27	)		(22.1	)		(131	)		(24.3	)		(186	)		(13.1	)
Fuel		(32	)		(30.5	)		N/A			N/A			(1	)		Large			(33	)		(31.1	)
Gas purchased for resale		(6	)		(9.5	)		(1	)		(10.0	)		7			Large			—			—
Operating revenues less purchased power, fuel and gas purchased for resale (net revenues)		118			6.1			(1	)		(0.7	)		24			75.0			141			6.7
Other operations and maintenance		41			6.4			4			6.0			—			—			45			6.1
Depreciation and amortization		11			5.6			1			9.1			(1	)		(50.0	)		11			5.2
Taxes, other than income taxes		30			6.9			4			33.3			—			—			34			7.6
Operating income		36			5.4			(10	)		(20.8	)		25			Large			51			7.2
Other income less deductions		(14	)		Large			—			—			3			Large			(11	)		Large
Net interest expense		(8	)		(5.7	)		(3	)		(33.3	)		(2	)		(28.6	)		(13	)		(8.3	)
Income before income tax expense		30			5.6			(7	)		(17.5	)		30			Large			53			9.5
Income tax expense		9			4.6			(2	)		(13.3	)		13			Large			20			9.8
Net income for common stock	$	21			6.3	%	$	(5	)		(20.0	)%	$	17			Large		$	33			9.4	%

(a) Includes inter-company and parent company accounting.

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

CECONY

	Three Months Ended September 30, 2011										Three Months Ended September 30, 2010
(Millions of Dollars)	Electric		Gas			Steam			2011 Total		Electric		Gas			Steam			2010 Total		2011-2010 Variation
Operating revenues	$	2,644	$	197		$	76		$	2,917	$	2,570	$	204		$	91		$	2,865	$	52
Purchased power		726		—			10			736		753		—			11			764		(28	)
Fuel		51		—			22			73		75		—			30			105		(32	)
Gas purchased for resale		—		57			—			57		—		63			—			63		(6	)
Net revenues		1,867		140			44			2,051		1,742		141			50			1,933		118
Operations and maintenance		559		82			37			678		506		85			46			637		41
Depreciation and amortization		166		28			15			209		156		26			16			198		11
Taxes, other than income taxes		384		53			25			462		365		46			21			432		30
Operating income	$	758	$	(23	)	$	(33	)	$	702	$	715	$	(16	)	$	(33	)	$	666	$	36

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Electric

CECONY’s results of electric operations for the three months ended September 30, 2011 compared with the 2010 period is as follows:

	Three Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010		Variation
Operating revenues	$	2,644	$	2,570	$	74
Purchased power		726		753		(27	)
Fuel		51		75		(24	)
Net revenues		1,867		1,742		125
Operations and maintenance		559		506		53
Depreciation and amortization		166		156		10
Taxes, other than income taxes		384		365		19
Electric operating income	$	758	$	715	$	43

CECONY’s electric sales and deliveries, excluding off-system sales, for the three months ended September 30, 2011 compared with the 2010 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011			September 30, 2010			Variation			Percent Variation
Residential/Religious (a)		3,808		3,774		34			0.9	%	$	999		$	1,020		$	(21	)		(2.1	)%
Commercial/Industrial		3,165		4,007		(842	)		(21.0	)		705			789			(84	)		(10.6	)
Retail access customers		7,151		6,822		329			4.8			766			652			114			17.5
NYPA, Municipal Agency and other sales		3,103		2,997		106			3.5			192			167			25			15.0
Other operating revenues		—		—		—			—			(18	)		(58	)		40			69.0
Total		17,227		17,600		(373	)		(2.1	)%	$	2,644		$	2,570		$	74			2.9	%

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

CECONY’s electric operating revenues increased $74 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to higher revenues from the electric rate plan ($123 million, which includes $43 million accrued revenues pursuant to the rate plan’s revenue decoupling mechanism), offset in part by lower purchased power ($27 million) and fuel costs ($24 million). CECONY’s 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. 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.

Electric delivery volumes in CECONY’s service area decreased 2.1 percent in the three months ended September 30, 2011 compared with the 2010 period. After adjusting for variations, principally weather and billing days, electric delivery volumes in CECONY’s service area decreased 0.4 percent in the three months ended September 30, 2011 compared with the 2010 period.

CECONY’s electric purchased power costs decreased $27 million in the three months ended September 30, 2011 compared with the 2010 period due to a decrease in purchased volumes ($22 million) and unit costs ($5 million). Electric fuel costs decreased $24 million in the three months ended September 30, 2011 compared with the 2010 period due to lower sendout volumes from the company’s electric generating facilities ($15 million) and unit costs ($9 million).

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CECONY’s electric operating income increased $43 million in the three months ended September 30, 2011 compared with the 2010 period. The increase reflects primarily higher net revenues ($125 million, due primarily to the electric rate plan ($123 million), including the collection of a surcharge for a New York State assessment ($43 million)). The increase in electric net revenues was offset by higher operations and maintenance costs ($53 million, due primarily to higher pension expense ($35 million) and employees’ health insurance costs ($13 million)), taxes, other than income taxes ($19 million, principally property taxes) and depreciation and amortization ($10 million). Most of the operating expenses in the 2011 period attributable to Hurricane Irene were deferred as a regulatory asset. See “Regulatory Assets and Liabilities” in Note B to the Third Quarter Financial Statements.

Gas

CECONY’s results of gas operations for the three months ended September 30, 2011 compared with the 2010 period is as follows:

	Three Months Ended
(Millions of Dollars)	September 30, 2011			September 30, 2010			Variation
Operating revenues	$	197		$	204		$	(7	)
Gas purchased for resale		57			63			(6	)
Net revenues		140			141			(1	)
Operations and maintenance		82			85			(3	)
Depreciation and amortization		28			26			2
Taxes, other than income taxes		53			46			7
Gas operating income	$	(23	)	$	(16	)	$	(7	)

CECONY’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, 2011 compared with the 2010 period were:

	Thousands of dths Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011			September 30, 2010		Variation			Percent Variation
Residential		2,984		3,267		(283	)		(8.7	)%	$	82		$	85	$	(3	)		(3.5	)%
General		3,453		2,912		541			18.6			45			44		1			2.3
Firm transportation		6,751		6,312		439			7.0			45			45		—			—
Total firm sales and transportation		13,188		12,491		697			5.6			172			174		(2	)		(1.1	)
Interruptible sales (a)		2,020		1,795		225			12.5			9			8		1			12.5
NYPA		13,401		6,795		6,606			97.2			1			1		—			—
Generation plants		26,501		33,268		(6,767	)		(20.3	)		9			10		(1	)		(10.0	)
Other		4,425		4,382		43			1.0			7			7		—			—
Other operating revenues		—		—		—			—			(1	)		4		(5	)		Large
Total		59,535		58,731		804			1.4	%	$	197		$	204	$	(7	)		3.4	%

(a) Includes 1,138 mdths and 781 mdths for the three months ended September 30, 2011 and 2010, respectively, which are also reflected in firm transportation and other.

CECONY’s gas operating revenues decreased $7 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to a decrease in gas purchased for resale costs ($6 million). CECONY’s revenues from gas sales 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. Other gas operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plans.

CECONY’s sales and transportation volumes for firm customers increased 5.6 percent in the three months ended September 30, 2011 compared with the 2010 period. After adjusting for variations, principally weather and billing days, firm gas sales and transportation volumes in the company’s service area increased 5.6 percent.

48

CECONY’s purchased gas cost decreased $6 million in the three months ended September 30, 2011 compared with the 2010 period due to lower unit costs ($9 million), offset by higher sendout volumes ($3 million).

CECONY’s gas operating income decreased $7 million in the three months ended September 30, 2011 compared with the 2010 period. The decrease reflects primarily higher taxes, other than income taxes ($7 million, principally property taxes), depreciation and amortization ($2 million) and lower net revenues ($1 million), offset by lower operations and maintenance costs ($3 million).

Steam

CECONY’s results of steam operations for the three months ended September 30, 2011 compared with the 2010 period is as follows:

	Three Months Ended
(Millions of Dollars)	September 30, 2011			September 30, 2010			Variation
Operating revenues	$	76		$	91		$	(15	)
Purchased power		10			11			(1	)
Fuel		22			30			(8	)
Net revenues		44			50			(6	)
Operations and maintenance		37			46			(9	)
Depreciation and amortization		15			16			(1	)
Taxes, other than income taxes		25			21			4
Steam operating income	$	(33	)	$	(33	)	$	—

CECONY’s steam sales and deliveries for the three months ended September 30, 2011 compared with the 2010 period were:

	Millions of Pounds Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011			September 30, 2010		Variation			Percent Variation
General		15		17		(2	)		(11.8	)%	$	2		$	2	$	—			—	%
Apartment house		799		788		11			1.4			17			16		1			6.3
Annual power		3,440		3,964		(524	)		(13.2	)		58			70		(12	)		(17.1	)
Other operating revenues		—		—		—			—			(1	)		3		(4	)		Large
Total		4,254		4,769		(515	)		(10.8	)%	$	76		$	91	$	(15	)		(16.5	)%

CECONY’s steam operating revenues decreased $15 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to lower purchased fuel costs ($8 million) and the net change in rates under the steam rate plans ($4 million). Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plans.

Steam sales and delivery volumes decreased 10.8 percent in the three months ended September 30, 2011 compared with the 2010 period. After adjusting for variations, principally weather and billing days, steam sales and deliveries decreased 9.3 percent in the three months ended September 30, 2011.

CECONY’s steam purchased fuel costs decreased $8 million in the three months ended September 30, 2011 compared with the 2010 period due to lower unit costs ($6 million) and sendout volumes ($2 million). Steam purchased power costs decreased $1 million in the three months ended September 30, 2011 compared with the 2010 period due to a decrease in unit costs ($1 million).

Steam operating income was the same in the three months ended September 30, 2011 compared with the 2010 period.

49

Other Income (Deductions)

Other income (deductions) decreased $14 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to lower financing charges on changes in World Trade Center regulatory assets and liabilities ($7 million) and lower income from the Company’s supplemental retirement program trust ($3 million) . See “Cash Flows from Operating Activities,” above and “Regulatory Assets and Liabilities” in Note B to the Third Quarter Financial Statements.

Net Interest Expense

Net interest expense decreased $8 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to lower interest rates on long-term debt during the 2011 period.

O&R

	Three Months Ended September 30, 2011							Three Months Ended September 30, 2010
(Millions of Dollars)	Electric		Gas			2011 Total		Electric		Gas			2010 Total		2011-2010 Variation
Operating revenues	$	217	$	24		$	241	$	245	$	25		$	270	$	(29	)
Purchased power		95		—			95		122		—			122		(27	)
Gas purchased for resale		—		9			9		—		10			10		(1	)
Net revenues		122		15			137		123		15			138		(1	)
Operations and maintenance		56		15			71		54		13			67		4
Depreciation and amortization		9		3			12		8		3			11		1
Taxes, other than income taxes		13		3			16		9		3			12		4
Operating income	$	44	$	(6	)	$	38	$	52	$	(4	)	$	48	$	(10	)

Electric

O&R’s results of electric operations for the three months ended September 30, 2011 compared with the 2010 period is as follows:

	Three Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010		Variation
Operating revenues	$	217	$	245	$	(28	)
Purchased power		95		122		(27	)
Net revenues		122		123		(1	)
Operations and maintenance		56		54		2
Depreciation and amortization		9		8		1
Taxes, other than income taxes		13		9		4
Electric operating income	$	44	$	52	$	(8	)

O&R’s electric sales and deliveries, excluding off-system sales, for the three months ended September 30, 2011 compared with the 2010 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011			September 30, 2010			Variation			Percent Variation
Residential/Religious (a)		578		655		(77	)		(11.8	)%	$	113		$	130		$	(17	)		(13.1	)%
Commercial/Industrial		315		420		(105	)		(25.0	)		49			66			(17	)		(25.8	)
Retail access customers		789		717		72			10.0			53			47			6			12.8
Public authorities		33		31		2			6.5			3			3			—			—
Other operating revenues		—		—		—			—			(1	)		(1	)		—			—
Total		1,715		1,823		(108	)		(5.9	)%	$	217		$	245		$	(28	)		(11.4	)%

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

50

O&R’s electric operating revenues decreased $28 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to lower purchased power costs ($27 million). 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 revenue decoupling mechanism, and as a result, changes in such volumes do impact revenues. Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s electric rate plan. See “Rate Agreements – O&R – Electric” in Note B to the Third Quarter Financial Statements.

Electric delivery volumes in O&R’s service area decreased 5.9 percent in the three months ended September 30, 2011 compared with the 2010 period. After adjusting for variations, principally weather, electric delivery volumes in O&R’s service area decreased 5.8 percent in the three months ended September 30, 2011 compared with the 2010 period.

Electric operating income decreased $8 million in the three months ended September 30, 2011 compared with the 2010 period. The decrease reflects primarily higher taxes, other than income taxes ($4 million, principally property taxes), operations and maintenance costs ($2 million), depreciation and amortization ($1 million) and lower net revenues ($1 million). Most of the operating expenses in the 2011 period attributable to Hurricane Irene were deferred as a regulatory asset.

Gas

O&R’s results of gas operations for the three months ended September 30, 2011 compared with the 2010 period is as follows:

	Three Months Ended
(Millions of Dollars)	September 30, 2011			September 30, 2010			Variation
Operating revenues	$	24		$	25		$	(1	)
Gas purchased for resale		9			10			(1	)
Net revenues		15			15			—
Operations and maintenance		15			13			2
Depreciation and amortization		3			3			—
Taxes, other than income taxes		3			3			—
Gas operating income	$	(6	)	$	(4	)	$	(2	)

O&R’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, 2011 compared with the 2010 period were:

	Thousands of dths Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011		September 30, 2010		Variation			Percent Variation
Residential		509		491		18			3.7	%	$	8	$	10	$	(2	)		(20.0	)%
General		104		108		(4	)		(3.7	)		1		1		—			—
Firm transportation		966		922		44			4.8			8		7		1			14.3
Total firm sales and transportation		1,579		1,521		58			3.8			17		18		(1	)		(5.6	)
Interruptible sales		907		953		(46	)		(4.8	)		1		1		—			—
Generation plants		359		286		73			25.5			—		—		—			—
Other		77		74		3			4.1			—		—		—			—
Other gas revenues		—		—		—			—			6		6		—			—
Total		2,922		2,834		88			3.1	%	$	24	$	25	$	(1	)		(4.0	)%

51

O&R’s gas operating revenues decreased $1 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to the decrease in gas purchased for resale costs ($1 million).

Sales and transportation volumes for firm customers increased 3.8 percent in the three months ended September 30, 2011 compared with the 2010 period. After adjusting for weather and other variations, total firm sales and transportation volumes increased 4.8 percent in the three months ended September 30, 2011 compared with the 2010 period. O&R’s New York 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.

Gas operating income decreased $2 million in the three months ended September 30, 2011 compared with the 2010 period.

Competitive Energy Businesses

The competitive energy businesses’ results of operations for the three months ended September 30, 2011 compared with the 2010 period is as follows:

	Three Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010			Variation
Operating revenues	$	472	$	584		$	(112	)
Purchased power		408		550			(142	)
Gas purchased for resale		6		1			5
Net revenues		58		33			25
Operations and maintenance		35		34			1
Depreciation and amortization		1		2			(1	)
Taxes, other than income taxes		6		5			1
Operating income	$	16	$	(8	)	$	24

The competitive energy businesses’ operating revenues were $112 million lower in the three months ended September 30, 2011 compared with the 2010 period. Electric wholesale revenues decreased $58 million in the three months ended September 30, 2011 compared with the 2010 period due to lower sales volume ($47 million) and unit prices ($11 million). Electric retail revenues decreased $53 million in the three months ended September 30, 2011 compared with the 2010 period due to lower unit prices ($39 million) and sales volume ($14 million). Gross margins on electric retail revenues decreased in the three months ended September 30, 2011 compared with the 2010 period due primarily to lower unit gross margins. Net mark-to-market values increased $26 million in the three months ended September 30, 2011 as compared with the 2010 period, of which $33 million in gains are reflected in purchased power costs and $7 million in losses are reflected in revenues. Other revenues increased $6 million in the three months ended September 30, 2011 as compared with the 2010 period due primarily to higher other wholesale revenue ($7 million).

Purchased power costs decreased $142 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to changes in mark-to-market values ($33 million) and lower purchased power costs ($110 million, due to lower unit prices ($61 million) and sales volumes ($49 million)). Operating income increased $24 million in the three months ended September 30, 2011 compared with the 2010 period due primarily to net mark-to-market effects ($26 million).

Other

For Con Edison, “Other” also includes inter-company eliminations relating to operating revenues and operating expenses.

52

Nine Months Ended September 30, 2011 Compared with Nine Months Ended September 30, 2010

The Companies’ results of operations in 2011 compared with 2010 were:

	CECONY						O&R						Competitive Energy Businesses and 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
Operating revenues	$	27			0.3	%	$	(49	)		(6.9	)%	$	(191	)		(13.1	)%	$	(213	)		(2.1	)%
Purchased power		(262	)		(12.5	)		(62	)		(22.1	)		(260	)		(19.6	)		(584	)		(15.7	)
Fuel		(26	)		(7.6	)		N/A			N/A			1			Large			(25	)		(7.3	)
Gas purchased for resale		4			1.0			(6	)		(8.8	)		11			Large			9			1.9
Operating revenues less purchased power, fuel and gas purchased for resale (net revenues)		311			6.0			19			5.3			57			43.8			387			6.8
Other operations and maintenance		74			4.0			12			6.0			10			11.8			96			4.5
Depreciation and amortization		32			5.5			3			9.1			(2	)		(28.6	)		33			5.3
Taxes, other than income taxes		98			8.0			4			10.8			2			14.3			104			8.1
Operating income		107			7.1			—			—			47			Large			154			9.5
Other income less deductions		(26	)		Large			3			Large			6			75.0			(17	)		(56.7	)
Net interest expense		(10	)		(2.4	)		1			4.0			1			5.6			(8	)		(1.8	)
Income before income tax expense		91			8.1			2			3.0			52			Large			145			12.1
Income tax expense		21			5.2			—			—			23			Large			44			10.2
Net income for common stock	$	70			9.9	%	$	2			4.8	%	$	29			Large		$	101			13.3	%

(a) Includes inter-company and parent company accounting.

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

CECONY

	Nine Months Ended September 30, 2011								Nine Months Ended September 30, 2010
(Millions of Dollars)	Electric		Gas		Steam		2011 Total		Electric		Gas		Steam		2010 Total		2011- 2010 Variation
Operating revenues	$	6,378	$	1,156	$	508	$	8,042	$	6,402	$	1,126	$	487	$	8,015	$	27
Purchased power		1,799		—		41		1,840		2,060		—		42		2,102		(262	)
Fuel		167		—		150		317		192		—		151		343		(26	)
Gas purchased for resale		—		412		—		412		—		408		—		408		4
Net revenues		4,412		744		317		5,473		4,150		718		294		5,162		311
Operations and maintenance		1,522		275		109		1,906		1,443		247		142		1,832		74
Depreciation and amortization		489		82		47		618		464		76		46		586		32
Taxes, other than income taxes		1,075		175		80		1,330		1,015		152		65		1,232		98
Operating income	$	1,326	$	212	$	81	$	1,619	$	1,228	$	243	$	41	$	1,512	$	107

53

Electric

CECONY’s results of electric operations for the nine months ended September 30, 2011 compared with the 2010 period is as follows:

	Nine Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010		Variation
Operating revenues	$	6,378	$	6,402	$	(24	)
Purchased power		1,799		2,060		(261	)
Fuel		167		192		(25	)
Net revenues		4,412		4,150		262
Operations and maintenance		1,522		1,443		79
Depreciation and amortization		489		464		25
Taxes, other than income taxes		1,075		1,015		60
Electric operating income	$	1,326	$	1,228	$	98

CECONY’s electric sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2011 compared with the 2010 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011		September 30, 2010		Variation			Percent Variation
Residential/Religious (a)		8,934		8,937		(3	)		—	%	$	2,299	$	2,333	$	(34	)		(1.5	)%
Commercial/Industrial		8,639		9,822		(1,183	)		(12.0	)		1,823		1,986		(163	)		(8.2	)
Retail access customers		18,339		17,533		806			4.6			1,794		1,620		174			10.7
NYPA, Municipal Agency and other sales		8,407		8,544		(137	)		(1.6	)		448		411		37			9.0
Other operating revenues		—		—		—			—			14		52		(38	)		(73.1	)
Total		44,319		44,836		(517	)		(1.2	)%	$	6,378	$	6,402	$	(24	)		(0.4	)%

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

CECONY’s electric operating revenues decreased $24 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to lower purchased power ($261 million) and fuel costs ($25 million), offset in part by higher revenues from the electric rate plan ($266 million, which reflects among other things, reconciliations of costs for municipal infrastructure support and capital expenditures ($7 million)). CECONY’s 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. 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.

Electric delivery volumes in CECONY’s service area decreased 1.2 percent in the nine months ended September 30, 2011 compared with the 2010 period. After adjusting for variations, principally weather and billing days, electric delivery volumes in CECONY’s service area decreased 1.0 percent in the nine months ended September 30, 2011 compared with the 2010 period.

CECONY’s electric purchased power costs decreased $261 million in the nine months ended September 30, 2011 compared with the 2010 period due to a decrease in unit costs ($172 million) and purchased volumes ($89 million). Electric fuel costs decreased $25 million in the nine months ended September 30, 2011 compared with the 2010 period due to lower unit costs ($13 million) and sendout volumes from the company’s electric generating facilities ($12 million).

54

CECONY’s electric operating income increased $98 million in the nine months ended September 30, 2011 compared with the 2010 period. The increase reflects primarily higher net revenues ($262 million, due primarily to the electric rate plan ($266 million)). The increase in electric net revenues was offset by higher operations and maintenance costs ($79 million, due primarily to higher pension expense ($64 million) and employees’ health insurance costs ($23 million), offset in part by lower costs for injuries and damages ($6 million) and cost control efforts), taxes, other than income taxes ($60 million, principally property taxes) and depreciation and amortization ($25 million). Most of the operating expenses in the 2011 period attributable to Hurricane Irene were deferred as a regulatory asset. See “Regulatory Assets and Liabilities” in Note B to the Third Quarter Financial Statements.

Gas

CECONY’s results of gas operations for the nine months ended September 30, 2011 compared with the 2010 period is as follows:

	Nine Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010		Variation
Operating revenues	$	1,156	$	1,126	$	30
Gas purchased for resale		412		408		4
Net revenues		744		718		26
Operations and maintenance		275		247		28
Depreciation and amortization		82		76		6
Taxes, other than income taxes		175		152		23
Gas operating income	$	212	$	243	$	(31	)

CECONY’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2011 compared with the 2010 period were:

	Thousands of dths Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011			September 30, 2010			Variation			Percent Variation
Residential		30,384		28,609		1,775			6.2	%	$	553		$	563		$	(10	)		(1.8	)%
General		20,896		18,956		1,940			10.2			269			275			(6	)		(2.2	)
Firm transportation		41,859		38,600		3,259			8.4			263			260			3			1.2
Total firm sales and transportation		93,139		86,165		6,974			8.1			1,085			1,098			(13	)		(1.2	)
Interruptible sales (a)		8,278		6,367		1,911			30.0			65			41			24			58.5
NYPA		24,536		18,917		5,619			29.7			2			2			—			—
Generation plants		60,706		65,483		(4,777	)		(7.3	)		25			27			(2	)		(7.4	)
Other		17,245		16,369		876			5.4			40			40			—			—
Other operating revenues		—		—		—			—			(61	)		(82	)		21			(25.6	)
Total		203,904		193,301		10,603			5.5	%	$	1,156		$	1,126		$	30			2.7	%

(a) Includes 3,214 mdths and 2,230 mdths for the nine months ended September 30, 2011 and 2010, respectively, which are also reflected in firm transportation and other.

CECONY’s gas operating revenues increased $30 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to higher revenues from the gas rate plans ($50 million).

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

CECONY’s sales and transportation volumes for firm customers increased 8.1 percent in the nine months ended September 30, 2011 compared with the 2010 period. After adjusting for variations, principally weather and billing days, firm gas sales and transportation volumes in the company’s service area increased 2.3 percent in the nine months ended September 30, 2011.

55

CECONY’s purchased gas cost increased $4 million in the nine months ended September 30, 2011 compared with the 2010 period due to higher sendout volumes ($38 million), offset by lower unit costs ($34 million).

CECONY’s gas operating income decreased $31 million in the nine months ended September 30, 2011 compared with the 2010 period. The decrease reflects primarily higher operations and maintenance costs ($28 million, due primarily to an increase in pension expense ($18 million) and employees’ health insurance costs ($5 million)), taxes, other than income taxes ($23 million, principally property taxes) and depreciation and amortization ($6 million), offset by higher net revenues ($26 million).

Steam

CECONY’s results of steam operations for the nine months ended September 30, 2011 compared with the 2010 period is as follows:

	Nine Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010		Variation
Operating revenues	$	508	$	487	$	21
Purchased power		41		42		(1	)
Fuel		150		151		(1	)
Net revenues		317		294		23
Operations and maintenance		109		142		(33	)
Depreciation and amortization		47		46		1
Taxes, other than income taxes		80		65		15
Steam operating income	$	81	$	41	$	40

CECONY’s steam sales and deliveries for the nine months ended September 30, 2011 compared with the 2010 period were:

	Millions of Pounds Delivered									Revenues in Millions
	Nine Months Ended									Nine Months Ended
Description	September 30, 2011		September 30, 2010		Variation		Percent Variation			September 30, 2011			September 30, 2010		Variation			Percent Variation
General		422		383		39		10.2	%	$	22		$	19	$	3			15.8	%
Apartment house		4,515		4,254		261		6.1			131			116		15			12.9
Annual power		13,041		13,034		7		0.1			375			347		28			8.1
Other operating revenues		—		—		—		—			(20	)		5		(25	)		Large
Total		17,978		17,671		307		1.7	%	$	508		$	487	$	21			4.3	%

CECONY’s steam operating revenues increased $21 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to the colder winter weather in 2011 compared with the 2010 period ($17 million) and the net change in rates under the steam rate plan ($8 million), offset in part by lower purchased power ($1 million) and fuel costs ($1 million). Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plans.

Steam sales and delivery volumes increased 1.7 percent in the nine months ended September 30, 2011 compared with the 2010 period. After adjusting for variations, principally weather and billing days, steam sales and deliveries decreased 3.6 percent in the nine months ended September 30, 2011 reflecting lower average normalized use per customer.

CECONY’s steam purchased fuel costs decreased $1 million in the nine months ended September 30, 2011 compared with the 2010 period. Steam purchased power costs decreased $1 million in the nine months ended September 30, 2011 compared with the 2010 period due to a decrease in unit costs ($7 million), offset by an increase in purchased volumes ($6 million).

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Steam operating income increased $40 million in the nine months ended September 30, 2011 compared with the 2010 period. The increase reflects primarily higher net revenues ($23 million) and lower operations and maintenance costs ($33 million, due primarily to lower pension expense ($26 million)), offset by higher taxes, other than income taxes ($15 million, principally property taxes) and depreciation and amortization ($1 million).

Other Income (Deductions)

Other income (deductions) decreased $26 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to lower financing charges on changes in World Trade Center regulatory assets and liabilities ($12 million) and lower allowance for equity funds used during construction ($4 million). See “Cash Flows from Operating Activities,” above and “Regulatory Assets and Liabilities” in Note B to the Third Quarter Financial Statements.

Net Interest Expense

Net interest expense decreased $10 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to lower interest rates on long-term debt in the 2011 period.

O&R

	Nine Months Ended September 30, 2011						Nine Months Ended September 30, 2010
(Millions of Dollars)	Electric		Gas		2011 Total		Electric		Gas		2010 Total		2011-2010 Variation
Operating revenues	$	507	$	153	$	660	$	559	$	150	$	709	$	(49	)
Purchased power		218		—		218		280		—		280		(62	)
Gas purchased for resale		—		62		62		—		68		68		(6	)
Net revenues		289		91		380		279		82		361		19
Operations and maintenance		164		48		212		157		43		200		12
Depreciation and amortization		26		10		36		24		9		33		3
Taxes, other than income taxes		30		11		41		27		10		37		4
Operating income	$	69	$	22	$	91	$	71	$	20	$	91	$	—

Electric

O&R’s results of electric operations for the nine months ended September 30, 2011 compared with the 2010 period is as follows:

	Nine Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010		Variation
Operating revenues	$	507	$	559	$	(52	)
Purchased power		218		280		(62	)
Net revenues		289		279		10
Operations and maintenance		164		157		7
Depreciation and amortization		26		24		2
Taxes, other than income taxes		30		27		3
Electric operating income	$	69	$	71	$	(2	)

O&R’s electric sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2011 compared with the 2010 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011			September 30, 2010			Variation			Percent Variation
Residential/Religious (a)		1,388		1,522		(134	)		(8.8	)%	$	253		$	283		$	(30	)		(10.6	)%
Commercial/Industrial		912		1,168		(256	)		(21.9	)		128			169			(41	)		(24.3	)
Retail access customers		2,079		1,770		309			17.5			121			102			19			18.6
Public authorities		83		85		(2	)		(2.4	)		8			9			(1	)		(11.1	)
Other operating revenues		—		—		—			—			(3	)		(4	)		1			25.0
Total		4,462		4,545		(83	)		(1.8	)%	$	507		$	559		$	(52	)		(9.3	)%

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

57

O&R’s electric operating revenues decreased $52 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to lower costs for purchased power ($62 million). 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 revenue decoupling mechanism, and as a result, changes in such volumes do impact revenues. Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s electric rate plan.

Electric delivery volumes in O&R’s service area decreased 1.8 percent in the nine months ended September 30, 2011 compared with the 2010 period. After adjusting for variations, principally weather, electric delivery volumes in O&R’s service area decreased 1.6 percent in the nine months ended September 30, 2011 compared with the 2010 period.

Electric operating income decreased $2 million in the nine months ended September 30, 2011 compared with the 2010 period. The decrease reflects primarily higher operations and maintenance costs ($7 million, due primarily to higher pension expense ($5 million)), taxes, other than income taxes ($3 million, principally property taxes) and depreciation and amortization ($2 million), offset by higher net revenues ($10 million)). Most of the operating expenses in the 2011 period attributable to Hurricane Irene were deferred as a regulatory asset.

Gas

O&R’s results of gas operations for the nine months ended September 30, 2011 compared with the 2010 period is as follows:

	Nine Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010		Variation
Operating revenues	$	153	$	150	$	3
Gas purchased for resale		62		68		(6	)
Net revenues		91		82		9
Operations and maintenance		48		43		5
Depreciation and amortization		10		9		1
Taxes, other than income taxes		11		10		1
Gas operating income	$	22	$	20	$	2

O&R’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2011 compared with the 2010 period were:

	Thousands of dths Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2011		September 30, 2010		Variation			Percent Variation			September 30, 2011		September 30, 2010		Variation			Percent Variation
Residential		5,162		4,843		319			6.6	%	$	76	$	75	$	1			1.3	%
General		1,013		971		42			4.3			13		13		—			—
Firm transportation		7,728		6,968		760			10.9			52		44		8			18.2
Total firm sales and transportation		13,903		12,782		1,121			8.8			141		132		9			6.8
Interruptible sales		3,213		3,418		(205	)		(6.0	)		3		8		(5	)		(62.5	)
Generation plants		1,109		688		421			61.2			—		—		—			—
Other		612		550		62			11.3			—		—		—			—
Other gas revenues		—		—		—			—			9		10		(1	)		(10.0	)
Total		18,837		17,438		1,399			8.0	%	$	153	$	150	$	3			2.0	%

58

O&R’s gas operating revenues increased $3 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to the gas rate plan, offset in part by the decrease in gas purchased for resale ($6 million).

Sales and transportation volumes for firm customers increased 8.8 percent in the nine months ended September 30, 2011 compared with the 2010 period. After adjusting for weather and other variations, total firm sales and transportation volumes decreased 0.6 percent in the nine months ended September 30, 2011 compared with the 2010 period. O&R’s New York 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.

Gas operating income increased $2 million in the nine months ended September 30, 2011 compared with the 2010 period. The increase reflects primarily higher net revenues ($9 million), offset by higher operations and maintenance costs ($5 million), depreciation and amortization ($1 million) and taxes, other than income taxes ($1 million, principally property taxes).

Competitive Energy Businesses

The competitive energy businesses’ results of operations for the nine months ended September 30, 2011 compared with the 2010 period is as follows:

	Nine Months Ended
(Millions of Dollars)	September 30, 2011		September 30, 2010		Variation
Operating revenues	$	1,286	$	1,490	$	(204	)
Purchased power		1,076		1,351		(275	)
Gas purchased for resale		17		7		10
Net revenues		193		132		61
Operations and maintenance		97		86		11
Depreciation and amortization		5		7		(2	)
Taxes, other than income taxes		16		14		2
Operating income	$	75	$	25	$	50

The competitive energy businesses’ operating revenues decreased $204 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to a decrease in electric revenues ($189 million) and mark-to-market effects ($33 million), offset in part by an increase in other revenues ($18 million). Electric wholesale revenues decreased $122 million in the nine months ended September 30, 2011 compared with the 2010 period due to lower sales volume ($106 million) and unit prices ($16 million). Electric retail revenues decreased $67 million in the nine months ended September 30, 2011 compared with the 2010 period due to lower unit prices ($64 million) and sales volume ($3 million). Gross margins on electric retail revenues decreased in the nine months ended September 30, 2011 compared with the 2010 period due primarily to lower unit gross margins. Net mark-to-market values increased $60 million in the nine months ended September 30, 2011 as compared with the 2010 period, of which $93 million in gains are reflected in purchased power costs and $33 million in losses are reflected in revenues. Other revenues increased $18 million in the nine months ended September 30, 2011 as compared with the 2010 period due primarily to higher other wholesale revenue ($11 million) and sales of energy efficiency services ($7 million).

Purchased power costs decreased $275 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to changes in mark-to-market values ($93 million) and lower purchased power costs ($182 million, due to lower unit prices ($96 million) and volumes ($86 million)). Operating income increased $50 million in the nine months ended September 30, 2011 compared with the 2010 period due primarily to net mark-to-market effects ($60 million), offset by lower electric wholesale and retail gross margins ($10 million).

Other

For Con Edison, “Other” also includes inter-company eliminations relating to operating revenues and operating expenses.

59

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.

In January 2011, the Companies implemented a consolidation, reporting, and analysis system as part of a large ongoing project to implement a new financial and supply-chain enterprise resource planning information system. The Companies are undertaking the project with the objective of improving business processes and information systems. The Companies expect the project to reduce costs, improve support of operating activities, reduce financial reporting risks, and simplify compliance activities. The Companies expect the project to enhance the processes used by employees to record financial transactions and analyze data; purchase materials and services and manage inventory; develop business plans and budgets and report financial and purchasing data. The project is reasonably likely to materially affect the Companies’ internal control over financial reporting.

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

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Part II Other Information

Item 1: Legal Proceedings

For information about certain legal proceedings affecting the Companies, see Notes B, F and G 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 other than as described below:

A Cyber Attack Could Adversely Affect the Companies. The Utilities and other operators of critical energy infrastructure may face a heightened risk of cyber attack. In the event of such an attack, the Utilities and the competitive energy businesses could have their operations disrupted, property damaged and customer information stolen; experience substantial loss of revenues, response costs and other financial loss; and be subject to increased regulation, litigation and damage to their reputation.

Item 2: Unregistered Sales of Equity Securities and Use of Proceeds

ISSUER PURCHASES OF EQUITY SECURITIES

Period	Total Number of Shares (or Units) Purchased*		Average Price Paid per Share (or Unit)		Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Appropriate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs
July 1, 2011 to July 31, 2011		155,136	$	53.89		—		—
August 1, 2011 to August 31, 2011		191,723		55.10		—		—
September 1, 2011 to September 30, 2011		199,497		56.54		—		—
Total		546,356	$	55.28		—		—

* Represents Con Edison common shares purchased in open-market transactions. The number of shares purchased approximated the number of treasury shares used for the company’s employee stock plans.

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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, 2011 and 2010, and the 12-month period ended December 31, 2010.
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, 2011 and 2010, and the 12-month period ended December 31, 2010.
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.

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SIGNATURES

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

	CONSOLIDATED EDISON, INC.
	CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.
DATE: November 3, 2011	By	/S/    ROBERT HOGLUND
		Robert Hoglund Senior Vice President, Chief Financial Officer and Duly Authorized Officer

63

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, 2011		For the Twelve Months Ended December 31, 2010		For the Nine Months Ended September 30, 2010
Earnings
Net income from continuing operations	$	860	$	992	$	759
Preferred stock dividend		8		11		9
(Income) or loss from equity investees		—		2		—
Minority interest loss		—		—		—
Income tax		477		548		433
Pre-tax income from continuing operations	$	1,345	$	1,553	$	1,201
Add: Fixed charges*		483		660		495
Add: Distributed income of equity investees		—		—		—
Subtract: Interest capitalized		—		—		—
Subtract: Pre-tax preferred stock dividend requirement		14		19		15
Earnings	$	1,814	$	2,194	$	1,681
* Fixed charges
Interest on long-term debt	$	423	$	580	$	437
Amortization of debt discount, premium and expense		14		17		13
Interest capitalized		—		—		—
Other interest		15		21		13
Interest component of rentals		17		23		17
Pre-tax preferred stock dividend requirement		14		19		15
Fixed charges	$	483	$	660	$	495
Ratio of Earnings to Fixed Charges		3.8		3.3		3.4

EX-31.1.1

Exhibit 31.1.1

CERTIFICATIONS

CON EDISON—Principal Executive Officer

I, Kevin Burke, the principal executive officer of Consolidated Edison, Inc., certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2011 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 function):

(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, 2011

/s/ Kevin Burke

Kevin Burke

Chairman, President and Chief Executive Officer

EX-31.1.2

Exhibit 31.1.2

CERTIFICATIONS

CON EDISON—Principal Financial Officer

I, Robert Hoglund, the principal financial officer of Consolidated Edison, Inc., certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2011 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 function):

(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, 2011

/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, Kevin Burke, 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, 2011, 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/ Kevin Burke

Kevin Burke

Dated: November 3, 2011

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, 2011, 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

Dated: November 3, 2011

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, 2011		For the Twelve Months Ended December 31, 2010		For the Nine Months Ended September 30, 2010
Earnings
Net income for common stock	$	779	$	893	$	709
Preferred stock dividend		8		11		8
(Income) or loss from equity investees		—		2		—
Minority interest loss		—		—		—
Income tax		425		495		404
Pre-tax income for common stock	$	1,212	$	1,401	$	1,121
Add: Fixed charges*		422		578		435
Add: Distributed income of equity investees		—		—		—
Subtract: Interest capitalized		—		—		—
Subtract: Pre-tax preferred stock dividend requirement		—		—		—
Earnings	$	1,634	$	1,979	$	1,556
* Fixed charges
Interest on long-term debt	$	379	$	520	$	393
Amortization of debt discount, premium and expense		14		17		13
Interest capitalized		—		—		—
Other interest		13		19		14
Interest component of rentals		16		22		15
Pre-tax preferred stock dividend requirement		—		—		—
Fixed charges	$	422	$	578	$	435
Ratio of Earnings to Fixed Charges		3.9		3.4		3.6

EX-31.2.1

Exhibit 31.2.1

CERTIFICATIONS

CECONY—Principal Executive Officer

I, Kevin Burke, the principal executive officer of Consolidated Edison Company of New York, Inc., certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2011 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 function):

(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, 2011

/s/ Kevin Burke

Kevin Burke

Chairman and Chief Executive Officer

EX-31.2.2

Exhibit 31.2.2

CERTIFICATIONS

CECONY—Principal Financial Officer

I, Robert Hoglund, the principal financial officer of Consolidated Edison Company of New York, Inc., certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2011 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 function):

(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, 2011

/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, Kevin Burke, 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, 2011, 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/ Kevin Burke

Kevin Burke

Dated: November 3, 2011

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, 2011, 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

Dated: November 3, 2011

XML

Fair Value Measurements (Reconciliation Of The Beginning And Ending Net Balances For Assets And Liabilities Measured At Level 3 Fair Value) (Details) (USD $) In Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2011		Sep. 30, 2010		Sep. 30, 2011		Sep. 30, 2010
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ 71		$ (19)		$ 3		$ 22
Included in Earnings	(31)		(34)		(8)		(70)
Included in Regulatory Assets and Liabilities	7		(10)		54		(53)
Purchases	8		1		22		2
Issuances
Sales
Settlements	5		4		(16)		18
Transfers In/Out of Level 3	24		(2)		29		21
Ending Balance	84		(60)		84		(60)
Commodity [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	(25)		(101)		(88)		(59)
Included in Earnings	(27)		(34)		(5)		(68)
Included in Regulatory Assets and Liabilities	9		(12)		54		(56)
Purchases	8		1		22		2
Issuances
Sales
Settlements	4		4		(19)		16
Transfers In/Out of Level 3	24		(2)		29		21
Ending Balance	(7)		(144)		(7)		(144)
Fair Value Interest Rate Contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	(10)		(12)		(10)		(11)
Included in Earnings	(1)				(3)		(2)
Included in Regulatory Assets and Liabilities	1				1		(1)
Issuances
Sales
Settlements	1				3		2
Ending Balance	(9)		(12)		(9)		(12)
Fair Value Other Assets [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	106	[1]	94	[1]	101	[1]	92	[1]
Included in Earnings	(3)	[1]
Included in Regulatory Assets and Liabilities	(3)	[1]	2	[1]	(1)	[1]	4	[1]
Issuances		[1]		[1]		[1]		[1]
Sales		[1]		[1]		[1]		[1]
Ending Balance	$ 100	[1]	$ 96	[1]	$ 100	[1]	$ 96	[1]

[1] Amounts included in earnings are reported in investment and other income on the consolidated income statement.

XML

Consolidated Statement Of Cash Flows (USD $) In Millions	9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010
OPERATING ACTIVITIES
Net Income	$ 869	$ 768
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	659	626
Deferred income taxes	368	562
Common equity component of allowance for funds used during construction	(8)	(13)
Net derivative (gains)/losses	(25)	35
Other non-cash items (net)	45	(8)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	(4)	(114)
Materials and supplies, including fuel oil and gas in storage	(27)	(9)
Other receivables and other current assets	70	(114)
Prepayments	(128)	(473)
Accounts payable	(50)	(105)
Pensions and retiree benefits	(1)	(33)
Accrued taxes	76	63
Accrued interest	57	45
Deferred charges, deferred derivative losses, noncurrent assets and other regulatory assets	92	(472)
Deferred credits and other regulatory liabilities	158	142
Other assets		(8)
Other liabilities	10	82
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,161	974
INVESTING ACTIVITIES
Utility construction expenditures	(1,412)	(1,455)
Cost of removal less salvage	(123)	(103)
Non-utility construction expenditures	(57)	(6)
Proceeds from investment tax credits and grants related to renewable energy investments	4
Net investment in Pilesgrove solar project	(31)	(3)
Common equity component of allowance for funds used during construction	8	13
Purchase of additional ownership interest in Honeoye Storage Corporation		(12)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,611)	(1,566)
FINANCING ACTIVITIES
Net proceeds from short-term debt		846
Issuance of long-term debt		870
Retirement of long-term debt	(3)	(781)
Issuance of common stock	81	78
Repurchase of common stock	(40)
Debt issuance costs		(6)
Common stock dividends	(519)	(468)
Preferred stock dividends	(9)	(9)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	(490)	530
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	60	(62)
BALANCE AT BEGINNING OF PERIOD	338	260
BALANCE AT END OF PERIOD	398	198
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest	371	394
Income taxes	(132)	284
CECONY [Member]
OPERATING ACTIVITIES
Net Income	788	717
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	618	586
Deferred income taxes	309	562
Common equity component of allowance for funds used during construction	(6)	(10)
Other non-cash items (net)	98	(88)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	3	(84)
Materials and supplies, including fuel oil and gas in storage	2	(9)
Other receivables and other current assets	243	(208)
Prepayments	(303)	(309)
Accounts payable	(45)	(96)
Pensions and retiree benefits	(5)	(30)
Accrued taxes	(7)	20
Accrued interest	46	37
Deferred charges, deferred derivative losses, noncurrent assets and other regulatory assets	33	(374)
Deferred credits and other regulatory liabilities	167	131
Other liabilities	19	93
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,960	938
INVESTING ACTIVITIES
Utility construction expenditures	(1,338)	(1,371)
Cost of removal less salvage	(118)	(100)
Common equity component of allowance for funds used during construction	6	10
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,450)	(1,461)
FINANCING ACTIVITIES
Net proceeds from short-term debt		832
Issuance of long-term debt		700
Retirement of long-term debt		(625)
Debt issuance costs		(6)
Capital contribution by parent		36
Dividend to parent	(509)	(502)
Preferred stock dividends	(9)	(8)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	(518)	427
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(8)	(96)
BALANCE AT BEGINNING OF PERIOD	78	131
BALANCE AT END OF PERIOD	70	35
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest	336	357
Income taxes	$ (103)	$ 263

XML

Consolidated Balance Sheet (USD $) In Millions	Sep. 30, 2011	Dec. 31, 2010
CURRENT ASSETS
Cash and temporary cash investments	$ 398	$ 338
Accounts receivable - customers, less allowance for uncollectible accounts	1,177	1,173
Accrued unbilled revenue	479	633
Other receivables, less allowance for uncollectible accounts	297	293
Fuel oil, gas in storage, materials and supplies, at average cost	375	348
Prepayments	469	341
Regulatory assets	110	203
Other current assets	153	178
TOTAL CURRENT ASSETS	3,458	3,507
INVESTMENTS	474	403
UTILITY PLANT, AT ORIGINAL COST
General	1,907	1,911
TOTAL	29,147	28,144
Less: Accumulated depreciation	5,961	5,808
Net	23,186	22,336
Construction work in progress	1,404	1,458
NET UTILITY PLANT	24,590	23,794
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	47	46
Construction work in progress	61	23
NET PLANT	24,698	23,863
OTHER NONCURRENT ASSETS
Goodwill	429	429
Intangible assets, less accumulated amortization of $3 in 2011 and 2010	3	3
Regulatory assets	7,206	7,683
Other deferred charges and noncurrent assets	267	298
TOTAL OTHER NONCURRENT ASSETS	7,905	8,413
TOTAL ASSETS	36,535	36,186
CURRENT LIABILITIES
Long-term debt due within one year	305	5
Accounts payable	1,062	1,151
Customer deposits	302	289
Accrued taxes	166	90
Accrued interest	212	155
Accrued wages	94	102
Fair value of derivative liabilities	101	125
Regulatory liabilities	257	295
Other current liabilities	460	459
TOTAL CURRENT LIABILITIES	2,959	2,671
NONCURRENT LIABILITIES
Obligations under capital leases	2	7
Provision for injuries and damages	180	165
Pensions and retiree benefits	2,600	3,287
Superfund and other environmental costs	496	512
Asset retirement obligations	114	109
Fair value of derivative liabilities	30	77
Other noncurrent liabilities	118	113
TOTAL NONCURRENT LIABILITIES	3,540	4,270
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	7,110	6,602
Regulatory liabilities	821	652
Other deferred credits	69	46
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	8,000	7,300
LONG-TERM DEBT	10,369	10,671
SHAREHOLDER'S EQUITY
Common shareholders' equity (See Statement of Shareholders' Equity)	11,454	11,061
Preferred stock of subsidiary	213	213
TOTAL SHAREHOLDER'S EQUITY	11,667	11,274
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	36,535	36,186
CECONY [Member] | Steam Plant [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	1,960	2,038
Steam Plant [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	1,960	2,038
CECONY [Member] | Electric Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	19,508	18,735
Electric Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	20,714	19,851
CECONY [Member] | Gas Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	4,051	3,844
Gas Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	4,566	4,344
CECONY [Member]
CURRENT ASSETS
Cash and temporary cash investments	70	78
Accounts receivable - customers, less allowance for uncollectible accounts	1,022	1,025
Accrued unbilled revenue	358	473
Other receivables, less allowance for uncollectible accounts	82	73
Accounts receivable from affiliated companies	24	273
Fuel oil, gas in storage, materials and supplies, at average cost	304	306
Prepayments	385	82
Regulatory assets	90	151
Other current assets	90	104
TOTAL CURRENT ASSETS	2,425	2,565
INVESTMENTS	178	167
UTILITY PLANT, AT ORIGINAL COST
General	1,736	1,746
TOTAL	27,255	26,363
Less: Accumulated depreciation	5,443	5,314
Net	21,812	21,049
Construction work in progress	1,333	1,345
NET UTILITY PLANT	23,145	22,394
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	6	7
NET PLANT	23,151	22,401
OTHER NONCURRENT ASSETS
Regulatory assets	6,668	7,097
Other deferred charges and noncurrent assets	232	244
TOTAL OTHER NONCURRENT ASSETS	6,900	7,341
TOTAL ASSETS	32,654	32,474
CURRENT LIABILITIES
Long-term debt due within one year	300
Accounts payable	836	924
Accounts payable to affiliated companies	15	13
Customer deposits	289	276
Accrued taxes	27	34
Accrued taxes to affiliated companies	29	29
Accrued interest	176	130
Accrued wages	91	93
Fair value of derivative liabilities	51	71
Regulatory liabilities	230	267
Other current liabilities	407	400
TOTAL CURRENT LIABILITIES	2,451	2,237
NONCURRENT LIABILITIES
Obligations under capital leases	2	7
Provision for injuries and damages	173	159
Pensions and retiree benefits	2,259	2,900
Superfund and other environmental costs	377	392
Asset retirement obligations	114	109
Fair value of derivative liabilities	9	29
Other noncurrent liabilities	110	102
TOTAL NONCURRENT LIABILITIES	3,044	3,698
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	6,539	6,071
Regulatory liabilities	706	547
Other deferred credits	65	42
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	7,310	6,660
LONG-TERM DEBT	9,444	9,743
SHAREHOLDER'S EQUITY
Common shareholders' equity (See Statement of Shareholders' Equity)	10,192	9,923
Preferred stock of subsidiary	213	213
TOTAL SHAREHOLDER'S EQUITY	10,405	10,136
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	$ 32,654	$ 32,474

XML

Regulatory Matters (Tables)

9 Months Ended

Sep. 30, 2011

Regulatory Matters [Abstract]

Regulatory Assets And Liabilities

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Regulatory assets
Unrecognized pension and other postretirement costs	$	3,769	$	4,371	$	3,584	$	4,152
Future federal income tax		1,763		1,593		1,688		1,515
Environmental remediation costs		681		695		563		574
Pension and other post retirement benefits deferrals		198		138		156		90
Revenue taxes		160		145		155		140
Surcharge for New York State assessment		150		121		138		112
Net electric deferrals		126		156		126		156
Deferred storm costs		81		57		61		43
O&R transition bond charges		45		48		—		—
Deferred derivative losses – long-term		34		74		21		48
Workers' compensation		25		31		24		31
Accrued unbilled revenues		22		—		22		—
Property tax reconciliation		12		34		—		27
World Trade Center restoration costs		9		45		9		45
Recoverable energy cost		2		42		2		42
Other		129		133		119		122
Regulatory assets – long-term		7,206		7,683		6,668		7,097
Deferred derivative losses – current		110		190		90		151
Recoverable energy costs – current		—		13		—		—
Regulatory assets – current		110		203		90		151
Total Regulatory Assets	$	7,316	$	7,886	$	6,758	$	7,248
Regulatory liabilities
Allowance for cost of removal less salvage	$	440	$	422	$	365	$	350
World Trade Center settlement proceeds		62		—		62		—
Carrying charges on transmission and distribution net plant		39		28		12		5
Bonus depreciation		24		1		23		1
Energy efficiency programs		23		12		21		11
Gas line losses		21		—		21		—
New York State tax refund		20		30		20		30
Gain on sale of properties		14		28		14		28
Expenditure prudence proceeding		11		—		11		—
Other		167		131		157		122
Regulatory liabilities – long-term		821		652		706		547
Net unbilled revenue deferrals – current		116		136		115		135
Revenue decoupling mechanism		99		38		99		38
Refundable energy cost – current		38		117		13		91
Deferred derivative gains – current		4		4		3		3
Regulatory liabilities – current		257		295		230		267
Total Regulatory Liabilities	$	1,078	$	947	$	936	$	814

XML

Document And Entity Information	9 Months Ended
	Sep. 30, 2011	Oct. 28, 2011
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2011
Document Fiscal Year Focus	2011
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		292,904,646
Consolidated Edison Co Of New York Inc [Member]
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

Fair Value Measurements (Narrative) (Details) (USD $) In Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Fair Value Measurements [Abstract]
Gain (loss) on Level 3 energy derivative assets	$ 1		$ (1)	$ 47
Gains (loss) on Level 3 energy derivative liabilities		14
Loss on Level 3 energy derivative assets for purchased power costs	(13)		26
Gain (loss) on Level 3 energy derivative liabilities for purchased power costs		(33)		(73)
Fair value, assets measured on recurring basis, change in unrealized gain (loss) included in other income	(10)	(3)	(35)	(2)
Fair value, assets measured on recurring basis, change in unrealized gain (loss) included in purchased power costs	$ (5)	$ (22)	$ 31	$ (29)

XML

Environmental Matters (Tables)

9 Months Ended

Sep. 30, 2011

Environmental Matters [Abstract]

Accrued Liabilities And Regulatory Assets

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Accrued Liabilities:
Manufactured gas plant sites	$	432	$	446	$	314	$	327
Other Superfund Sites		64		66		63		65
Total	$	496	$	512	$	377	$	392
Regulatory assets	$	681	$	695	$	563	$	574

Environmental Remediation Costs

	For the Three Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Remediation costs incurred	$	9	$	9	$	9	$	8
	For the Nine Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Remediation costs incurred	$	24	$	32	$	22	$	30

Accrued Liabilities For Asbestos Suits And Workers' Compensation Proceedings

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Accrued liability – asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets – asbestos suits	$	10	$	10	$	10	$	10
Accrued liability – workers' compensation	$	99	$	106	$	94	$	101
Regulatory assets – workers' compensation	$	25	$	31	$	24	$	31

XML

Derivative Instruments And Hedging Activities (Aggregate Fair Value Of All Derivative Instruments With Credit Risk Related Contingent Features) (Details) (USD $) In Millions	Sep. 30, 2011
Derivatives, Fair Value [Line Items]
Aggregate fair value - net liabilities	$ 128	[1]
Collateral posted	34	[1],[2]
Additional Collateral Required Due To Loss Of Unsecured Credit [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	146
Additional Collateral Aggregate Fair Value Down One Level [Member]
Derivatives, Fair Value [Line Items]
Additional collateral	11	[1],[3],[4]
Additional Collateral Aggregate Fair Value Down Below Investment Grade [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	16
Additional collateral	$ 143	[1],[3],[4],[5]

[1] 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 Con Edison's competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post collateral, which at September 30, 2011, would have amounted to an estimated $146 million for Con Edison. 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.

[2] Across the Utilities' energy derivative positions, credit limits for the same counterparties are generally integrated. At September 30, 2011, the Utilities posted combined collateral of $34 million, including an estimated $5 million attributable to O&R.

[3] 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 of setoff.

[4] The current ratings are Moody's, S&P and Fitch long-term credit rating of, as applicable, Con Edison (Baa1/BBB+/BBB+), CECONY (A3/A-/A-) or O&R (Baa1/A-/A-). Credit ratings assigned by rating agencies are expressions of opinions that are subject to revision or withdrawal at any time by the assigning rating agency.

[5] Derivative instruments that are net assets have been excluded from the table. At September 30, 2011, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of an estimated $16 million.

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Short-Term Borrowing

9 Months Ended

Sep. 30, 2011

Short-Term Borrowing

Note C — Short-Term Borrowing

In October 2011, Con Edison and the Utilities entered into a Credit Agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis, and terminated their Amended and Restated Credit Agreement (Prior Credit Agreement) which was to expire in June 2012. Under the Credit Agreement, which expires in October 2016, there is a maximum of $2.25 billion of credit available, with the full amount available to CECONY and $1 billion available to Con Edison, including up to $1.2 billion of letters of credit. The Credit Agreement supports the Companies' commercial paper programs. The Companies have not borrowed under the Credit Agreement.

The banks' commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at September 30, 2011 this ratio was 0.48 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding 5 percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies' respective credit ratings.

At September 30, 2011 and December 31, 2010 Con Edison and CECONY had no commercial paper outstanding.

At September 30, 2011 and December 31, 2010, no loans were outstanding under the Companies' Credit Agreement or Prior Credit Agreement and $223 million (including $170 million for CECONY) and $197 million (including $145 million for CECONY) of letters of credit were outstanding under the Credit Agreement or Prior Credit Agreement, respectively.

CECONY [Member]

Short-Term Borrowing

Note C — Short-Term Borrowing

In October 2011, Con Edison and the Utilities entered into a Credit Agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis, and terminated their Amended and Restated Credit Agreement (Prior Credit Agreement) which was to expire in June 2012. Under the Credit Agreement, which expires in October 2016, there is a maximum of $2.25 billion of credit available, with the full amount available to CECONY and $1 billion available to Con Edison, including up to $1.2 billion of letters of credit. The Credit Agreement supports the Companies' commercial paper programs. The Companies have not borrowed under the Credit Agreement.

The banks' commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at September 30, 2011 this ratio was 0.48 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding 5 percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies' respective credit ratings.

At September 30, 2011 and December 31, 2010 Con Edison and CECONY had no commercial paper outstanding.

At September 30, 2011 and December 31, 2010, no loans were outstanding under the Companies' Credit Agreement or Prior Credit Agreement and $223 million (including $170 million for CECONY) and $197 million (including $145 million for CECONY) of letters of credit were outstanding under the Credit Agreement or Prior Credit Agreement, respectively.

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Other Material Contingencies (Tables)

9 Months Ended

Sep. 30, 2011

Other Material Contingencies [Abstract]

Total Guarantees

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	652	$	3	$	153	$	808
Intra-company guarantees		15		—		1		16
Other guarantees		25		13		—		38
TOTAL	$	692	$	16	$	154	$	862

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Derivative Instruments And Hedging Activities (Energy Price Hedging Fair Values) (Details) (USD $) In Millions	Sep. 30, 2011	Dec. 31, 2010
Derivative Instruments And Hedging Activities [Abstract]
Fair value of net derivative assets/(liabilities) - gross	$ (115)	$ (261)
Impact of netting of cash collateral	73	176
Fair value of net derivative assets/(liabilities) - net	$ (42)	$ (85)

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Environmental Matters (Accrued Liability For Asbestos Suits And Workers' Compensation Proceedings) (Details) (USD $) In Millions	Sep. 30, 2011	Dec. 31, 2010
Site Contingency [Line Items]
Regulatory assets	$ 7,316	$ 7,886
Asbestos Suits [Member]
Site Contingency [Line Items]
Accrued liability	10	10
Regulatory assets	10	10
Workers' Compensation [Member]
Site Contingency [Line Items]
Accrued liability	99	106
Regulatory assets	$ 25	$ 31

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Other Postretirement Benefits (Tables) (Other Postretirement Benefits [Member])

9 Months Ended

Sep. 30, 2011

Other Postretirement Benefits [Member]

Net Periodic Postretirement Benefit Costs

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost	$	7		$	6		$	5		$	5
Interest cost on accumulated other postretirement benefit obligation		20			23			18			20
Expected return on plan assets		(22	)		(22	)		(21	)		(19	)
Amortization of net actuarial loss		22			23			20			21
Amortization of prior service cost		(3	)		(3	)		(3	)		(4	)
Amortization of transition obligation		1			1			1			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	25		$	28		$	20		$	24
Cost capitalized		(9	)		(10	)		(7	)		(8	)
Cost deferred		3			2			3			1
Cost charged to operating expenses	$	19		$	20		$	16		$	17
	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost	$	19		$	18		$	15		$	15
Interest cost on accumulated other postretirement benefit obligation		62			69			54			60
Expected return on plan assets		(66	)		(66	)		(59	)		(57	)
Amortization of net actuarial loss		66			69			60			63
Amortization of prior service cost		(7	)		(9	)		(9	)		(12	)
Amortization of transition obligation		3			3			3			3
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	77		$	84		$	64		$	72
Cost capitalized		(27	)		(30	)		(22	)		(25	)
Cost deferred		12			2			10			(1	)
Cost charged to operating expenses	$	62		$	56		$	52		$	46

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Financial Information By Business Segment

9 Months Ended

Sep. 30, 2011

Financial Information By Business Segment

Note H — Financial Information by Business Segment

The financial data for the business segments are as follows:

	For the Three Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2011			2010			2011			2010			2011		2010		2011			2010
CECONY
Electric	$	2,644		$	2,570		$	3		$	3		$	166	$	156	$	758		$	715
Gas		197			204			1			1			28		26		(23	)		(16	)
Steam		76			91			20			18			15		16		(33	)		(33	)
Consolidation adjustments		—			—			(24	)		(22	)		—		—		—			—
Total CECONY	$	2,917		$	2,865		$	—		$	—		$	209	$	198	$	702		$	666
O&R
Electric	$	217		$	245		$	—		$	—		$	9	$	8	$	44		$	52
Gas		24			25			—			—			3		3		(6	)		(4	)
Total O&R	$	241		$	270		$	—		$	—		$	12	$	11	$	38		$	48
Competitive energy businesses	$	472		$	584		$	3		$	2		$	1	$	2	$	16		$	(8	)
Other*		(1	)		(12	)		(3	)		(2	)		—		—		—			(1	)
Total Con Edison	$	3,629		$	3,707		$	—		$	—		$	222	$	211	$	756		$	705

* Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

	For the Nine Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2011			2010			2011			2010			2011		2010		2011			2010
CECONY
Electric	$	6,378		$	6,402		$	9		$	9		$	489	$	464	$	1,326		$	1,228
Gas		1,156			1,126			4			4			82		76		212			243
Steam		508			487			59			55			47		46		81			41
Consolidation adjustments		—			—			(72	)		(68	)		—		—		—			—
Total CECONY	$	8,042		$	8,015		$	—		$	—		$	618	$	586	$	1,619		$	1,512
O&R
Electric	$	507		$	559		$	—		$	—		$	26	$	24	$	69		$	71
Gas		153			150			—			—			10		9		22			20
Total O&R	$	660		$	709		$	—		$	—		$	36	$	33	$	91		$	91
Competitive energy businesses	$	1,286		$	1,491		$	9		$	6		$	5	$	7	$	75		$	25
Other*		(16	)		(30	)		(9	)		(6	)		—		—		(2	)		(1	)
Total Con Edison	$	9,972		$	10,185		$	—		$	—		$	659	$	626	$	1,781		$	1,627

* Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

CECONY [Member]

Financial Information By Business Segment

Note H — Financial Information by Business Segment

The financial data for the business segments are as follows:

	For the Three Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2011			2010			2011			2010			2011		2010		2011			2010
CECONY
Electric	$	2,644		$	2,570		$	3		$	3		$	166	$	156	$	758		$	715
Gas		197			204			1			1			28		26		(23	)		(16	)
Steam		76			91			20			18			15		16		(33	)		(33	)
Consolidation adjustments		—			—			(24	)		(22	)		—		—		—			—
Total CECONY	$	2,917		$	2,865		$	—		$	—		$	209	$	198	$	702		$	666
O&R
Electric	$	217		$	245		$	—		$	—		$	9	$	8	$	44		$	52
Gas		24			25			—			—			3		3		(6	)		(4	)
Total O&R	$	241		$	270		$	—		$	—		$	12	$	11	$	38		$	48
Competitive energy businesses	$	472		$	584		$	3		$	2		$	1	$	2	$	16		$	(8	)
Other*		(1	)		(12	)		(3	)		(2	)		—		—		—			(1	)
Total Con Edison	$	3,629		$	3,707		$	—		$	—		$	222	$	211	$	756		$	705

* Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

	For the Nine Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2011			2010			2011			2010			2011		2010		2011			2010
CECONY
Electric	$	6,378		$	6,402		$	9		$	9		$	489	$	464	$	1,326		$	1,228
Gas		1,156			1,126			4			4			82		76		212			243
Steam		508			487			59			55			47		46		81			41
Consolidation adjustments		—			—			(72	)		(68	)		—		—		—			—
Total CECONY	$	8,042		$	8,015		$	—		$	—		$	618	$	586	$	1,619		$	1,512
O&R
Electric	$	507		$	559		$	—		$	—		$	26	$	24	$	69		$	71
Gas		153			150			—			—			10		9		22			20
Total O&R	$	660		$	709		$	—		$	—		$	36	$	33	$	91		$	91
Competitive energy businesses	$	1,286		$	1,491		$	9		$	6		$	5	$	7	$	75		$	25
Other*		(16	)		(30	)		(9	)		(6	)		—		—		(2	)		(1	)
Total Con Edison	$	9,972		$	10,185		$	—		$	—		$	659	$	626	$	1,781		$	1,627

* Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

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Consolidated Statement Of Common Shareholders' Equity (USD $) In Millions, except Share data	CECONY [Member] Common Stock [Member]	CECONY [Member] Additional Paid-In Capital [Member]	CECONY [Member] Retained Earnings [Member]	CECONY [Member] Repurchased Con Edison Stock [Member]	CECONY [Member] Capital Stock Expense [Member]	CECONY [Member] Accumulated Other Comprehensive Income/(Loss) [Member]	CECONY [Member]	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Treasury Stock [Member]	Capital Stock Expense [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Total
BEGINNING BALANCE at Dec. 31, 2009	$ 589	$ 3,877	$ 5,909	$ (962)	$ (62)	$ (4)	$ 9,347	$ 30	$ 4,420	$ 6,904	$ (1,001)	$ (62)	$ (42)	$ 10,249
BEGINNING BALANCE (in shares) at Dec. 31, 2009	235,488,094							281,123,741			23,210,700
Net income			246				246
Capital contribution from parent		12					12
Net income for common stock										226				226
Common stock dividends			(167)				(167)			(167)				(167)
Cumulative preferred dividends			(3)				(3)
Issuance of common shares - dividend reinvestment and employee stock plans (in shares)								647,731
Issuance of common shares - dividend reinvestment and employee stock plans									28					28
Other comprehensive income													3	3
ENDING BALANCE at Mar. 31, 2010	589	3,889	5,985	(962)	(62)	(4)	9,435	30	4,448	6,963	(1,001)	(62)	(39)	10,339
ENDING BALANCE (in shares) at Mar. 31, 2010	235,488,094							281,771,472			23,210,700
BEGINNING BALANCE at Dec. 31, 2009	589			(962)	(62)	(4)	9,347				(1,001)	(62)		10,249
BEGINNING BALANCE (in shares) at Dec. 31, 2009	235,488,094										23,210,700
Net income							717							768
Net income for common stock							709							759
Cumulative preferred dividends							(8)							(9)
ENDING BALANCE at Sep. 30, 2010	589			(962)	(62)	(4)	9,591				(1,001)	(62)		10,630
ENDING BALANCE (in shares) at Sep. 30, 2010	235,488,094										23,210,700
BEGINNING BALANCE at Mar. 31, 2010	589	3,889	5,985	(962)	(62)	(4)	9,435	30	4,448	6,963	(1,001)	(62)	(39)	10,339
BEGINNING BALANCE (in shares) at Mar. 31, 2010	235,488,094							281,771,472			23,210,700
Net income			138				138
Capital contribution from parent		12					12
Net income for common stock										183				183
Common stock dividends			(168)				(168)			(168)				(168)
Cumulative preferred dividends			(3)				(3)
Issuance of common shares - dividend reinvestment and employee stock plans (in shares)								555,964
Issuance of common shares - dividend reinvestment and employee stock plans									25					25
Other comprehensive income													1	1
ENDING BALANCE at Jun. 30, 2010	589	3,901	5,952	(962)	(62)	(4)	9,414	30	4,473	6,978	(1,001)	(62)	(38)	10,380
ENDING BALANCE (in shares) at Jun. 30, 2010	235,488,094							282,327,436			23,210,700
Net income			335				335							353
Capital contribution from parent		12					12
Net income for common stock							332			350				350
Common stock dividends			(167)				(167)			(168)				(168)
Cumulative preferred dividends			(3)				(3)							(3)
Issuance of common shares - dividend reinvestment and employee stock plans (in shares)								1,487,598
Issuance of common shares - dividend reinvestment and employee stock plans								1	66					67
Other comprehensive income													1	1
ENDING BALANCE at Sep. 30, 2010	589	3,913	6,117	(962)	(62)	(4)	9,591	31	4,539	7,160	(1,001)	(62)	(37)	10,630
ENDING BALANCE (in shares) at Sep. 30, 2010	235,488,094							283,815,034			23,210,700
BEGINNING BALANCE at Dec. 31, 2010	589	4,234	6,132	(962)	(64)	(6)	9,923	31	4,915	7,220	(1,001)	(64)	(40)	11,061
BEGINNING BALANCE (in shares) at Dec. 31, 2010	235,488,094							291,616,334			23,210,700
Net income			271				271
Net income for common stock										311				311
Common stock dividends			(170)				(170)			(175)				(175)
Cumulative preferred dividends			(3)				(3)
Issuance of common shares - dividend reinvestment and employee stock plans (in shares)								656,049
Issuance of common shares - dividend reinvestment and employee stock plans								1	30					31
Other comprehensive income													3	3
ENDING BALANCE at Mar. 31, 2011	589	4,234	6,230	(962)	(64)	(6)	10,021	32	4,945	7,356		(64)	(37)	11,231
ENDING BALANCE (in shares) at Mar. 31, 2011	235,488,094							292,272,383
BEGINNING BALANCE at Dec. 31, 2010	589	4,234		(962)	(64)	(6)	9,923				(1,001)	(64)		11,061
BEGINNING BALANCE (in shares) at Dec. 31, 2010	235,488,094										23,210,700
Net income							788							869
Net income for common stock							779							860
Cumulative preferred dividends							(9)							(9)
ENDING BALANCE at Sep. 30, 2011	589	4,234		(962)	(64)	(6)	10,192					(64)		11,454
ENDING BALANCE (in shares) at Sep. 30, 2011	235,488,094
BEGINNING BALANCE at Mar. 31, 2011	589	4,234	6,230	(962)	(64)	(6)	10,021	32	4,945	7,356	(1,001)	(64)	(37)	11,231
BEGINNING BALANCE (in shares) at Mar. 31, 2011	235,488,094							292,272,383			23,210,700
Net income			160				160
Net income for common stock										165				165
Common stock dividends			(170)				(170)			(175)				(175)
Cumulative preferred dividends			(3)				(3)
Issuance of common shares - dividend reinvestment and employee stock plans (in shares)								603,513			(182,942)
Issuance of common shares - dividend reinvestment and employee stock plans									32		5			37
Common stock repurchases											(9)			(9)
Common stock repurchases, shares											178,942
Other comprehensive income													2	2
ENDING BALANCE at Jun. 30, 2011	589	4,234	6,217	(962)	(64)	(6)	10,008	32	4,977	7,346	(1,005)	(64)	(35)	11,251
ENDING BALANCE (in shares) at Jun. 30, 2011	235,488,094							292,875,896			23,206,700
Net income			356				356							386
Net income for common stock							353			383				383
Common stock dividends			(169)				(169)			(176)				(176)
Cumulative preferred dividends			(3)				(3)							(3)
Issuance of common shares - dividend reinvestment and employee stock plans (in shares)								8,000			(554,356)
Issuance of common shares - dividend reinvestment and employee stock plans									6		19			25
Common stock repurchases											(31)			(31)
Common stock repurchases, shares											546,356
Other comprehensive income													2	2
ENDING BALANCE at Sep. 30, 2011	$ 589	$ 4,234	$ 6,401	$ (962)	$ (64)	$ (6)	$ 10,192	$ 32	$ 4,983	$ 7,553	$ (1,017)	$ (64)	$ (33)	$ 11,454
ENDING BALANCE (in shares) at Sep. 30, 2011	235,488,094							292,883,896			23,198,700

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Other Postretirement Benefits (Net Periodic Postretirement Benefit Costs) (Details) (Other Postretirement Benefits [Member], USD $) In Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 7	$ 6	$ 19	$ 18
Interest cost on accumulated other postretirement benefit obligation	20	23	62	69
Expected return on plan assets	(22)	(22)	(66)	(66)
Amortization of net actuarial loss	22	23	66	69
Amortization of prior service cost	(3)	(3)	(7)	(9)
Amortization of transition obligation	1	1	3	3
NET PERIODIC POSTRETIREMENT BENEFIT COST	25	28	77	84
Cost capitalized	(9)	(10)	(27)	(30)
Cost deferred	3	2	12	2
Cost charged to operating expenses	19	20	62	56
Expected contributions	84		84
Contribution other postretirement benefit plans			$ 35

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Other Postretirement Benefits

9 Months Ended

Sep. 30, 2011

Other Postretirement Benefits

Note E — Other Postretirement Benefits

Net Periodic Benefit Cost

The components of the Companies' net periodic postretirement benefit costs for the three and nine months ended September 30, 2011 and 2010 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost	$	7		$	6		$	5		$	5
Interest cost on accumulated other postretirement benefit obligation		20			23			18			20
Expected return on plan assets		(22	)		(22	)		(21	)		(19	)
Amortization of net actuarial loss		22			23			20			21
Amortization of prior service cost		(3	)		(3	)		(3	)		(4	)
Amortization of transition obligation		1			1			1			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	25		$	28		$	20		$	24
Cost capitalized		(9	)		(10	)		(7	)		(8	)
Cost deferred		3			2			3			1
Cost charged to operating expenses	$	19		$	20		$	16		$	17
	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost	$	19		$	18		$	15		$	15
Interest cost on accumulated other postretirement benefit obligation		62			69			54			60
Expected return on plan assets		(66	)		(66	)		(59	)		(57	)
Amortization of net actuarial loss		66			69			60			63
Amortization of prior service cost		(7	)		(9	)		(9	)		(12	)
Amortization of transition obligation		3			3			3			3
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	77		$	84		$	64		$	72
Cost capitalized		(27	)		(30	)		(22	)		(25	)
Cost deferred		12			2			10			(1	)
Cost charged to operating expenses	$	62		$	56		$	52		$	46

Expected Contributions

Con Edison expects to make a contribution of $84 million, including $74 million for CECONY, to the other postretirement benefit plans in 2011. During the first nine months of 2011, Con Edison contributed $35 million to the other postretirement benefit plans (of which $30 million was contributed by CECONY).

CECONY [Member]

Other Postretirement Benefits

Note E — Other Postretirement Benefits

Net Periodic Benefit Cost

The components of the Companies' net periodic postretirement benefit costs for the three and nine months ended September 30, 2011 and 2010 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost	$	7		$	6		$	5		$	5
Interest cost on accumulated other postretirement benefit obligation		20			23			18			20
Expected return on plan assets		(22	)		(22	)		(21	)		(19	)
Amortization of net actuarial loss		22			23			20			21
Amortization of prior service cost		(3	)		(3	)		(3	)		(4	)
Amortization of transition obligation		1			1			1			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	25		$	28		$	20		$	24
Cost capitalized		(9	)		(10	)		(7	)		(8	)
Cost deferred		3			2			3			1
Cost charged to operating expenses	$	19		$	20		$	16		$	17
	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost	$	19		$	18		$	15		$	15
Interest cost on accumulated other postretirement benefit obligation		62			69			54			60
Expected return on plan assets		(66	)		(66	)		(59	)		(57	)
Amortization of net actuarial loss		66			69			60			63
Amortization of prior service cost		(7	)		(9	)		(9	)		(12	)
Amortization of transition obligation		3			3			3			3
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	77		$	84		$	64		$	72
Cost capitalized		(27	)		(30	)		(22	)		(25	)
Cost deferred		12			2			10			(1	)
Cost charged to operating expenses	$	62		$	56		$	52		$	46

Expected Contributions

Con Edison expects to make a contribution of $84 million, including $74 million for CECONY, to the other postretirement benefit plans in 2011. During the first nine months of 2011, Con Edison contributed $35 million to the other postretirement benefit plans (of which $30 million was contributed by CECONY).

XML

Fair Value Measurements

9 Months Ended

Sep. 30, 2011

Fair Value Measurements

Note J — 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.

The valuation technique used by the Companies with regard to commodity derivatives and other assets that fall into either Level 2 or Level 3 is the market approach, which uses prices and other relevant information generated by market transactions involving identical or comparable assets and liabilities. The valuation technique used by the Companies with regard to the interest rate contract that falls into Level 3 is the income approach which uses valuation techniques to convert future income stream amounts to a single amount in present value terms.

Assets and liabilities measured at fair value on a recurring basis as of September 30, 2011 are summarized as follows:

	Level 1				Level 2						Level 3						Netting Adjustments (4)						Total
(Millions of Dollars)	Con Edison		CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity	$	2	$	—	$	52		$	28		$	69		$	17		$	(44	)	$	(6	)	$	79		$	39
Transfer in (5) (6)		1		1		—			—			—			—			—			—			1			1
Transfer out (5) (6)		—		—		(1	)		(1	)		—			—			—			—			(1	)		(1	)
Commodity (1)		3		1		51			27			69			17			(44	)		(6	)		79			39
Other assets (3)		75		75		—			—			100			91			—			—			175			166
Total	$	78	$	76	$	51		$	27		$	169		$	108		$	(44	)	$	(6	)	$	254		$	205
Derivative liabilities:
Commodity	$	10	$	5	$	130		$	91		$	98		$	11		$	(117	)	$	(47	)	$	121		$	60
Transfer in (5) (7)		—		—		23			8			1			1			—			—			24			9
Transfer out (5) (7)		—		—		(1	)		(1	)		(23	)		(8	)		—			—			(24	)		(9	)
Commodity (1)	$	10	$	5	$	152		$	98		$	76		$	4		$	(117	)	$	(47	)	$	121		$	60
Interest rate contract (2)		—		—		—			—			9			—			—			—			9			—
Total	$	10	$	5	$	152		$	98		$	85		$	4		$	(117	)	$	(47	)	$	130		$	60

(1) A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

(2) See Note I.

(3) Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

(4) 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.

(5) The Companies' policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

(6) Transferred from Level 2 to Level 1 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

(7) Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2010 to less than one year as of September 30, 2011.

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2010 are summarized as follows:

	Level 1				Level 2						Level 3						Netting Adjustments (4)						Total
(Millions of Dollars)	Con Edison		CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity (1)	$	2	$	1	$	72		$	21		$	144		$	13		$	(112	)	$	13		$	106		$	48
Other assets (3)		65		64		—			—			101			92			—			—			166			156
Total	$	67	$	65	$	72		$	21		$	245		$	105		$	(112	)	$	13		$	272		$	204
Derivative liabilities:
Commodity	$	4	$	2	$	270		$	177		$	205		$	12		$	(288	)	$	(91	)	$	191		$	100
Transfer in (5) (6) (7)		—		—		(36	)		(36	)		(9	)		(9	)		—			—			(45	)		(45	)
Transfer out (5) (6) (7)		—		—		9			9			36			36			—			—			45			45
Commodity (1)	$	4	$	2	$	243		$	150		$	232		$	39		$	(288	)	$	(91	)	$	191		$	100
Interest rate contract (2)		—		—		—			—			10			—			—			—			10			—
Total	$	4	$	2	$	243		$	150		$	242		$	39		$	(288	)	$	(91	)	$	201		$	100

(1) A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

(2) See Note I.

(3) Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

(4) 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.

(5) The Companies' policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

(6) Transferred from Level 2 to Level 3 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

(7) Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2009 to less than one year as of December 31, 2010.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2011 and classified as Level 3 in the fair value hierarchy below.

	For the Three Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity	$	(25	)	$	(27	)	$	9		$	8	$	—	$	—	$	4	$	24	$	(7	)
Interest rate contract		(10	)		(1	)		1			—		—		—		1		—		(9	)
Other assets (1)		106			(3	)		(3	)		—		—		—		—		—		100
Total	$	71		$	(31	)	$	7		$	8	$	—	$	—	$	5	$	24	$	84
CECONY
Derivatives:
Commodity	$	—		$	(8	)	$	1		$	8	$	—	$		$	3	$	9	$	13
Other assets (1)		96			(3	)		(2	)		—		—				—		—		91
Total	$	96		$	(11	)	$	(1	)	$	8	$	—	$		$	3	$	9	$	104

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

	For the Nine Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	(5	)	$	54		$	22	$	—	$	—	$	(19	)	$	29	$	(7	)
Interest rate contract		(10	)		(3	)		1			—		—		—		3			—		(9	)
Other assets (1)		101			—			(1	)		—		—		—		—			—		100
Total	$	3		$	(8	)	$	54		$	22	$	—	$	—	$	(16	)	$	29	$	84
CECONY
Derivatives:
Commodity	$	(26	)	$	(11	)	$	22		$	18	$	—	$	—	$	(4	)	$	14	$	13
Other assets (1)		92			—			(1	)		—		—		—		—			—		91
Total	$	66		$	(11	)	$	21		$	18	$	—	$	—	$	(4	)	$	14	$	104

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2010 and classified as Level 3 in the fair value hierarchy below.

	For the Three Months Ended September 30, 2010
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2010			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of September 30, 2010
Con Edison
Derivatives:
Commodity	$	(101	)	$	(34	)	$	(12	)	$	1	$	—	$	—	$	4	$	(2	)	$	(144	)
Interest rate contract		(12	)		—			—			—		—		—		—		—			(12	)
Other assets (1)		94			—			2			—		—		—		—		—			96
Total	$	(19	)	$	(34	)	$	(10	)	$	1	$	—	$	—	$	4	$	(2	)	$	(60	)
CECONY
Derivatives:
Commodity	$	(30	)	$	(7	)	$	(3	)	$	1	$	—	$	—	$	4	$	(2	)	$	(37	)
Other assets (1)		85			—			2			—		—		—		—		—			87
Total	$	55		$	(7	)	$	(1	)	$	1	$	—	$	—	$	4	$	(2	)	$	50

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

	For Nine Months Ended September 30, 2010
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2010			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2010
Con Edison
Derivatives:
Commodity	$	(59	)	$	(68	)	$	(56	)	$	2	$	—	$	—	$	16		$	21	$	(144	)
Interest rate contract		(11	)		(2	)		(1	)		—		—		—		2			—		(12	)
Other assets (1)		92			—			4			—		—		—		—			—		96
Total	$	22		$	(70	)	$	(53	)	$	2	$	—	$	—	$	18		$	21	$	(60	)
CECONY
Derivatives:
Commodity	$	(5	)	$	(14	)	$	(37	)	$	—	$	—	$	—	$	(2	)	$	21	$	(37	)
Other assets (1)		83			—			4			—		—		—		—			—		87
Total	$	78		$	(14	)	$	(33	)	$	—	$	—	$	—	$	(2	)	$	21	$	(50	)

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

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 commissions. 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 ($1 million gain and $14 million gain) and purchased power costs ($13 million loss and $33 million loss) on the consolidated income statement for the three months ended September 30, 2011 and 2010, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($1 million loss and $47 million gain) and purchased power costs ($26 million gain and $73 million loss) on the consolidated income statement for the nine months ended September 30, 2011 and 2010, respectively. The change in fair value relating to Level 3 commodity derivative assets held at September 30, 2011 and 2010 is included in non-utility revenues ($10 million loss and $3 million loss), and purchased power costs ($5 million loss and $22 million loss) on the consolidated income statement for the three months ended September 30, 2011 and 2010, respectively. For the nine months ended September 30, 2011 and 2010, the change in fair value relating to Level 3 commodity derivative assets and liabilities included in non-utility revenues ($35 million loss and $2 million loss) and purchased power costs ($31 million gain and $29 million loss) on the consolidated income statement.

The accounting rules for fair value measurements and disclosures require consideration of the impact of non-performance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2011, the Companies determined that non-performance risk would not have a material impact on their financial position or results of operations. To assess non-performance risk, the Companies considered information such as collateral requirements, master netting arrangements, letters of credit and parent company guarantees, and applied a market-based method by using the counterparty's (for an asset) or the Companies' (for a liability) credit default swaps rates.

CECONY [Member]

Fair Value Measurements

Note J — 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.

The valuation technique used by the Companies with regard to commodity derivatives and other assets that fall into either Level 2 or Level 3 is the market approach, which uses prices and other relevant information generated by market transactions involving identical or comparable assets and liabilities. The valuation technique used by the Companies with regard to the interest rate contract that falls into Level 3 is the income approach which uses valuation techniques to convert future income stream amounts to a single amount in present value terms.

Assets and liabilities measured at fair value on a recurring basis as of September 30, 2011 are summarized as follows:

	Level 1				Level 2						Level 3						Netting Adjustments (4)						Total
(Millions of Dollars)	Con Edison		CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity	$	2	$	—	$	52		$	28		$	69		$	17		$	(44	)	$	(6	)	$	79		$	39
Transfer in (5) (6)		1		1		—			—			—			—			—			—			1			1
Transfer out (5) (6)		—		—		(1	)		(1	)		—			—			—			—			(1	)		(1	)
Commodity (1)		3		1		51			27			69			17			(44	)		(6	)		79			39
Other assets (3)		75		75		—			—			100			91			—			—			175			166
Total	$	78	$	76	$	51		$	27		$	169		$	108		$	(44	)	$	(6	)	$	254		$	205
Derivative liabilities:
Commodity	$	10	$	5	$	130		$	91		$	98		$	11		$	(117	)	$	(47	)	$	121		$	60
Transfer in (5) (7)		—		—		23			8			1			1			—			—			24			9
Transfer out (5) (7)		—		—		(1	)		(1	)		(23	)		(8	)		—			—			(24	)		(9	)
Commodity (1)	$	10	$	5	$	152		$	98		$	76		$	4		$	(117	)	$	(47	)	$	121		$	60
Interest rate contract (2)		—		—		—			—			9			—			—			—			9			—
Total	$	10	$	5	$	152		$	98		$	85		$	4		$	(117	)	$	(47	)	$	130		$	60

(1) A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

(2) See Note I.

(3) Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

(4) 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.

(5) The Companies' policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

(6) Transferred from Level 2 to Level 1 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

(7) Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2010 to less than one year as of September 30, 2011.

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2010 are summarized as follows:

	Level 1				Level 2						Level 3						Netting Adjustments (4)						Total
(Millions of Dollars)	Con Edison		CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity (1)	$	2	$	1	$	72		$	21		$	144		$	13		$	(112	)	$	13		$	106		$	48
Other assets (3)		65		64		—			—			101			92			—			—			166			156
Total	$	67	$	65	$	72		$	21		$	245		$	105		$	(112	)	$	13		$	272		$	204
Derivative liabilities:
Commodity	$	4	$	2	$	270		$	177		$	205		$	12		$	(288	)	$	(91	)	$	191		$	100
Transfer in (5) (6) (7)		—		—		(36	)		(36	)		(9	)		(9	)		—			—			(45	)		(45	)
Transfer out (5) (6) (7)		—		—		9			9			36			36			—			—			45			45
Commodity (1)	$	4	$	2	$	243		$	150		$	232		$	39		$	(288	)	$	(91	)	$	191		$	100
Interest rate contract (2)		—		—		—			—			10			—			—			—			10			—
Total	$	4	$	2	$	243		$	150		$	242		$	39		$	(288	)	$	(91	)	$	201		$	100

(1) A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

(2) See Note I.

(3) Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

(4) 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.

(5) The Companies' policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

(6) Transferred from Level 2 to Level 3 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

(7) Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2009 to less than one year as of December 31, 2010.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2011 and classified as Level 3 in the fair value hierarchy below.

	For the Three Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity	$	(25	)	$	(27	)	$	9		$	8	$	—	$	—	$	4	$	24	$	(7	)
Interest rate contract		(10	)		(1	)		1			—		—		—		1		—		(9	)
Other assets (1)		106			(3	)		(3	)		—		—		—		—		—		100
Total	$	71		$	(31	)	$	7		$	8	$	—	$	—	$	5	$	24	$	84
CECONY
Derivatives:
Commodity	$	—		$	(8	)	$	1		$	8	$	—	$		$	3	$	9	$	13
Other assets (1)		96			(3	)		(2	)		—		—				—		—		91
Total	$	96		$	(11	)	$	(1	)	$	8	$	—	$		$	3	$	9	$	104

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

	For the Nine Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	(5	)	$	54		$	22	$	—	$	—	$	(19	)	$	29	$	(7	)
Interest rate contract		(10	)		(3	)		1			—		—		—		3			—		(9	)
Other assets (1)		101			—			(1	)		—		—		—		—			—		100
Total	$	3		$	(8	)	$	54		$	22	$	—	$	—	$	(16	)	$	29	$	84
CECONY
Derivatives:
Commodity	$	(26	)	$	(11	)	$	22		$	18	$	—	$	—	$	(4	)	$	14	$	13
Other assets (1)		92			—			(1	)		—		—		—		—			—		91
Total	$	66		$	(11	)	$	21		$	18	$	—	$	—	$	(4	)	$	14	$	104

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2010 and classified as Level 3 in the fair value hierarchy below.

	For the Three Months Ended September 30, 2010
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2010			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of September 30, 2010
Con Edison
Derivatives:
Commodity	$	(101	)	$	(34	)	$	(12	)	$	1	$	—	$	—	$	4	$	(2	)	$	(144	)
Interest rate contract		(12	)		—			—			—		—		—		—		—			(12	)
Other assets (1)		94			—			2			—		—		—		—		—			96
Total	$	(19	)	$	(34	)	$	(10	)	$	1	$	—	$	—	$	4	$	(2	)	$	(60	)
CECONY
Derivatives:
Commodity	$	(30	)	$	(7	)	$	(3	)	$	1	$	—	$	—	$	4	$	(2	)	$	(37	)
Other assets (1)		85			—			2			—		—		—		—		—			87
Total	$	55		$	(7	)	$	(1	)	$	1	$	—	$	—	$	4	$	(2	)	$	50

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

	For Nine Months Ended September 30, 2010
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2010			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2010
Con Edison
Derivatives:
Commodity	$	(59	)	$	(68	)	$	(56	)	$	2	$	—	$	—	$	16		$	21	$	(144	)
Interest rate contract		(11	)		(2	)		(1	)		—		—		—		2			—		(12	)
Other assets (1)		92			—			4			—		—		—		—			—		96
Total	$	22		$	(70	)	$	(53	)	$	2	$	—	$	—	$	18		$	21	$	(60	)
CECONY
Derivatives:
Commodity	$	(5	)	$	(14	)	$	(37	)	$	—	$	—	$	—	$	(2	)	$	21	$	(37	)
Other assets (1)		83			—			4			—		—		—		—			—		87
Total	$	78		$	(14	)	$	(33	)	$	—	$	—	$	—	$	(2	)	$	21	$	(50	)

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

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 commissions. 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 ($1 million gain and $14 million gain) and purchased power costs ($13 million loss and $33 million loss) on the consolidated income statement for the three months ended September 30, 2011 and 2010, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($1 million loss and $47 million gain) and purchased power costs ($26 million gain and $73 million loss) on the consolidated income statement for the nine months ended September 30, 2011 and 2010, respectively. The change in fair value relating to Level 3 commodity derivative assets held at September 30, 2011 and 2010 is included in non-utility revenues ($10 million loss and $3 million loss), and purchased power costs ($5 million loss and $22 million loss) on the consolidated income statement for the three months ended September 30, 2011 and 2010, respectively. For the nine months ended September 30, 2011 and 2010, the change in fair value relating to Level 3 commodity derivative assets and liabilities included in non-utility revenues ($35 million loss and $2 million loss) and purchased power costs ($31 million gain and $29 million loss) on the consolidated income statement.

The accounting rules for fair value measurements and disclosures require consideration of the impact of non-performance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, 2011, the Companies determined that non-performance risk would not have a material impact on their financial position or results of operations. To assess non-performance risk, the Companies considered information such as collateral requirements, master netting arrangements, letters of credit and parent company guarantees, and applied a market-based method by using the counterparty's (for an asset) or the Companies' (for a liability) credit default swaps rates.

XML

Environmental Matters

9 Months Ended

Sep. 30, 2011

Environmental Matters

Note F — 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 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, 2011 and December 31, 2010 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Accrued Liabilities:
Manufactured gas plant sites	$	432	$	446	$	314	$	327
Other Superfund Sites		64		66		63		65
Total	$	496	$	512	$	377	$	392
Regulatory assets	$	681	$	695	$	563	$	574

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. Under their current rate agreements, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs. In February 2011, the NYSPSC initiated a proceeding to examine the existing mechanisms pursuant to which utilities recover such costs and possible alternatives.

Environmental remediation costs incurred related to Superfund Sites for the three and nine months ended September 30, 2011 and 2010, were as follows:

	For the Three Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Remediation costs incurred	$	9	$	9	$	9	$	8
	For the Nine Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Remediation costs incurred	$	24	$	32	$	22	$	30

There were no insurance recoveries related to Superfund Sites for the three months ended September 30, 2011 and 2010. Insurance recoveries related to Superfund Sites for the nine months ended September 30, 2011 and 2010 were immaterial.

In 2010, CECONY estimated that for its manufactured gas plant sites, its aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other manufactured gas plant-related environmental contaminants could range up to $1.9 billion. In 2010, O&R estimated that for its manufactured gas plant sites, each of which has been investigated, the aggregate undiscounted potential liability for the remediation of such contaminants could range up to $200 million. 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. In 2010, CECONY estimated that its aggregate undiscounted potential liability for these suits and additional suits that may be brought over the next 15 years is $10 million. The estimate was based upon a combination of modeling, historical data analysis and risk factor assessment. Actual experience may be materially different. 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 agreements, 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, 2011 and December 31, 2010 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Accrued liability – asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets – asbestos suits	$	10	$	10	$	10	$	10
Accrued liability – workers' compensation	$	99	$	106	$	94	$	101
Regulatory assets – workers' compensation	$	25	$	31	$	24	$	31

CECONY [Member]

Environmental Matters

Note F — 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 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, 2011 and December 31, 2010 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Accrued Liabilities:
Manufactured gas plant sites	$	432	$	446	$	314	$	327
Other Superfund Sites		64		66		63		65
Total	$	496	$	512	$	377	$	392
Regulatory assets	$	681	$	695	$	563	$	574

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. Under their current rate agreements, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs. In February 2011, the NYSPSC initiated a proceeding to examine the existing mechanisms pursuant to which utilities recover such costs and possible alternatives.

Environmental remediation costs incurred related to Superfund Sites for the three and nine months ended September 30, 2011 and 2010, were as follows:

	For the Three Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Remediation costs incurred	$	9	$	9	$	9	$	8
	For the Nine Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Remediation costs incurred	$	24	$	32	$	22	$	30

There were no insurance recoveries related to Superfund Sites for the three months ended September 30, 2011 and 2010. Insurance recoveries related to Superfund Sites for the nine months ended September 30, 2011 and 2010 were immaterial.

In 2010, CECONY estimated that for its manufactured gas plant sites, its aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other manufactured gas plant-related environmental contaminants could range up to $1.9 billion. In 2010, O&R estimated that for its manufactured gas plant sites, each of which has been investigated, the aggregate undiscounted potential liability for the remediation of such contaminants could range up to $200 million. 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. In 2010, CECONY estimated that its aggregate undiscounted potential liability for these suits and additional suits that may be brought over the next 15 years is $10 million. The estimate was based upon a combination of modeling, historical data analysis and risk factor assessment. Actual experience may be materially different. 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 agreements, 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, 2011 and December 31, 2010 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Accrued liability – asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets – asbestos suits	$	10	$	10	$	10	$	10
Accrued liability – workers' compensation	$	99	$	106	$	94	$	101
Regulatory assets – workers' compensation	$	25	$	31	$	24	$	31

XML

Regulatory Matters (Regulatory Assets And Liabilities) (Details) (USD $) In Millions	Sep. 30, 2011	Dec. 31, 2010
Regulatory Assets [Line Items]
Regulatory assets	$ 7,206	$ 7,683
Regulatory assets - current	110	203
Total Regulatory Assets	7,316	7,886
Regulatory liabilities	821	652
Regulatory liabilities - current	257	295
Total Regulatory Liabilities	1,078	947
Unrecognized Pension And Other Postretirement Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets	3,769	4,371
Future Federal Income Tax [Member]
Regulatory Assets [Line Items]
Regulatory assets	1,763	1,593
Environmental Remediation Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets	681	695
Pension And Other Post Retirement Benefits Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets	198	138
Revenue Taxes [Member]
Regulatory Assets [Line Items]
Regulatory assets	160	145
Surcharge For New York State Assessment [Member]
Regulatory Assets [Line Items]
Regulatory assets	150	121
Net Electric Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets	126	156
Deferred Storm Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets	81	57
O & R Transition Bond Charges [Member]
Regulatory Assets [Line Items]
Regulatory assets	45	48
Deferred Derivative Losses - Long-Term [Member]
Regulatory Assets [Line Items]
Regulatory assets	34	74
Workers' Compensation [Member]
Regulatory Assets [Line Items]
Regulatory assets	25	31
Accrued Unbilled Revenues [Member]
Regulatory Assets [Line Items]
Regulatory assets	22
Property Tax Reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory assets	12	34
World Trade Center Restoration Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets	9	45
Recoverable Energy Cost [Member]
Regulatory Assets [Line Items]
Regulatory assets	2	42
Other [Member]
Regulatory Assets [Line Items]
Regulatory assets	129	133
Deferred Derivative Losses - Current [Member]
Regulatory Assets [Line Items]
Regulatory assets - current	110	190
Recoverable Energy Costs - Current [Member]
Regulatory Assets [Line Items]
Regulatory assets - current		13
Allowance For Cost Of Removal Less Salvage [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	440	422
World Trade Center Settlement Proceeds [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	62
Carrying Charges On Transmission And Distribution Net Plant [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	39	28
Bonus Depreciation [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	24	1
Energy Efficiency Programs [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	23	12
Gas Line Losses [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	21
New York State Tax Refund [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	20	30
Gain On Sale Of Properties [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	14	28
Expenditure Prudence Proceeding [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	11
Other Liabilities [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	167	131
Net Unbilled Revenue Deferrals - Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	116	136
Revenue Decoupling Mechanism [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	99	38
Refundable Energy Cost - Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	38	117
Deferred Derivative Gains - Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	$ 4	$ 4

XML

Pension Benefits

9 Months Ended

Sep. 30, 2011

Pension Benefits

Note D — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies' net periodic benefit costs for the three and nine months ended September 30, 2011 and 2010 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost – including administrative expenses	$	48		$	42		$	45		$	39
Interest cost on projected benefit obligation		140			139			131			130
Expected return on plan assets		(184	)		(175	)		(174	)		(167	)
Amortization of net actuarial loss		133			106			126			100
Amortization of prior service costs		2			2			—			2
NET PERIODIC BENEFIT COST	$	139		$	114		$	128		$	104
Amortization of regulatory asset		—			—			—			—
TOTAL PERIODIC BENEFIT COST	$	139		$	114		$	128		$	104
Cost capitalized		(45	)		(40	)		(42	)		(36	)
Cost deferred		(11	)		(29	)		(11	)		(29	)
Cost charged to operating expenses	$	83		$	45		$	75		$	39
	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost – including administrative expenses	$	142		$	126		$	133		$	117
Interest cost on projected benefit obligation		420			417			393			390
Expected return on plan assets		(550	)		(527	)		(524	)		(501	)
Amortization of net actuarial loss		397			318			376			300
Amortization of prior service costs		6			6			4			6
NET PERIODIC BENEFIT COST	$	415		$	340		$	382		$	312
Amortization of regulatory asset*		1			1			1			1
TOTAL PERIODIC BENEFIT COST	$	416		$	341		$	383		$	313
Cost capitalized		(141	)		(118	)		(131	)		(109	)
Cost deferred		(68	)		(85	)		(70	)		(82	)
Cost charged to operating expenses	$	207		$	138		$	182		$	122

* Relates to increases in CECONY's pension obligations of $45 million from a 1999 special retirement program.

Expected Contributions

The Companies are not required under funding regulations and laws to make any contributions to the pension plan during 2011. The Companies' policy is to fund their accounting cost to the extent tax deductible. In 2011, Con Edison contributed $533 million to the pension plan (of which $491 million was contributed by CECONY). During the first nine months of 2010, Con Edison contributed $434 million to the pension plan (of which $397 million was contributed by CECONY). During the first nine months of 2011, the Companies funded $11 million for the non-qualified supplemental pension plans.

CECONY [Member]

Pension Benefits

Note D — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies' net periodic benefit costs for the three and nine months ended September 30, 2011 and 2010 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost – including administrative expenses	$	48		$	42		$	45		$	39
Interest cost on projected benefit obligation		140			139			131			130
Expected return on plan assets		(184	)		(175	)		(174	)		(167	)
Amortization of net actuarial loss		133			106			126			100
Amortization of prior service costs		2			2			—			2
NET PERIODIC BENEFIT COST	$	139		$	114		$	128		$	104
Amortization of regulatory asset		—			—			—			—
TOTAL PERIODIC BENEFIT COST	$	139		$	114		$	128		$	104
Cost capitalized		(45	)		(40	)		(42	)		(36	)
Cost deferred		(11	)		(29	)		(11	)		(29	)
Cost charged to operating expenses	$	83		$	45		$	75		$	39

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost – including administrative expenses	$	142		$	126		$	133		$	117
Interest cost on projected benefit obligation		420			417			393			390
Expected return on plan assets		(550	)		(527	)		(524	)		(501	)
Amortization of net actuarial loss		397			318			376			300
Amortization of prior service costs		6			6			4			6
NET PERIODIC BENEFIT COST	$	415		$	340		$	382		$	312
Amortization of regulatory asset*		1			1			1			1
TOTAL PERIODIC BENEFIT COST	$	416		$	341		$	383		$	313
Cost capitalized		(141	)		(118	)		(131	)		(109	)
Cost deferred		(68	)		(85	)		(70	)		(82	)
Cost charged to operating expenses	$	207		$	138		$	182		$	122

* Relates to increases in CECONY's pension obligations of $45 million from a 1999 special retirement program.

Expected Contributions

The Companies are not required under funding regulations and laws to make any contributions to the pension plan during 2011. The Companies' policy is to fund their accounting cost to the extent tax deductible. In 2011, Con Edison contributed $533 million to the pension plan (of which $491 million was contributed by CECONY). During the first nine months of 2010, Con Edison contributed $434 million to the pension plan (of which $397 million was contributed by CECONY). During the first nine months of 2011, the Companies funded $11 million for the non-qualified supplemental pension plans.

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Consolidated Statement Of Comprehensive Income (USD $) In Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
NET INCOME	$ 386	$ 353	$ 869	$ 768
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension plan liability adjustments	2	1	7	5
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	2	1	7	5
COMPREHENSIVE INCOME	388	354	876	773
Preferred stock dividend requirements of subsidiary	(3)	(3)	(9)	(9)
COMPREHENSIVE INCOME FOR COMMON STOCK	385	351	867	764
CECONY [Member]
NET INCOME	356	335	788	717
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Preferred stock dividend requirements of subsidiary	$ (3)	$ (3)	$ (9)	$ (8)

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General

9 Months Ended

Sep. 30, 2011

General

General

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

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

The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies' separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2010 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2011 and June 30, 2011. Certain prior period amounts have been reclassified to conform to the current period presentation.

Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiaries, provides electric service in southeastern New York and adjacent areas of northern New Jersey and eastern Pennsylvania and gas service in southeastern New York and adjacent areas of eastern Pennsylvania. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a retail energy services company that sells electricity and also offers energy-related services; Consolidated Edison Energy, Inc. (Con Edison Energy), a wholesale energy supply and services company; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops and participates in infrastructure projects.

CECONY [Member]

General

General

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

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

The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies' separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2010 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2011 and June 30, 2011. Certain prior period amounts have been reclassified to conform to the current period presentation.

Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiaries, provides electric service in southeastern New York and adjacent areas of northern New Jersey and eastern Pennsylvania and gas service in southeastern New York and adjacent areas of eastern Pennsylvania. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a retail energy services company that sells electricity and also offers energy-related services; Consolidated Edison Energy, Inc. (Con Edison Energy), a wholesale energy supply and services company; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops and participates in infrastructure projects.

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Other Material Contingencies (Total Guarantees) (Details) (USD $) In Millions	Sep. 30, 2011	Dec. 31, 2010
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 862	$ 859
Guarantee Duration, 0-3 Years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	692
Guarantee Duration, 0-3 Years [Member] | Financial And Performance Guarantee For Commodity Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	652
Guarantee Duration, 0-3 Years [Member] | Financial And Performance Guarantee For Intra-Company [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	15
Guarantee Duration, 0-3 Years [Member] | Financial And Performance Guarantee Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	25
Guarantee Duration, 4-10 Years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	16
Guarantee Duration, 4-10 Years [Member] | Financial And Performance Guarantee For Commodity Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	3
Guarantee Duration, 4-10 Years [Member] | Financial And Performance Guarantee For Intra-Company [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term
Guarantee Duration, 4-10 Years [Member] | Financial And Performance Guarantee Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	13
Guarantee Duration, Greater Than 10 Years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	154
Guarantee Duration, Greater Than 10 Years [Member] | Financial And Performance Guarantee For Commodity Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	153
Guarantee Duration, Greater Than 10 Years [Member] | Financial And Performance Guarantee For Intra-Company [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1
Guarantee Duration, Greater Than 10 Years [Member] | Financial And Performance Guarantee Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term
Financial And Performance Guarantee For Commodity Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	808
Financial And Performance Guarantee For Intra-Company [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	16
Financial And Performance Guarantee Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 38

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Summary Of Significant Accounting Policies (Earnings Per Common Share) (Details) (USD $) In Millions, except Per Share data	3 Months Ended						9 Months Ended
	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Sep. 30, 2011	Sep. 30, 2010
Summary Of Significant Accounting Policies [Abstract]
Net income for common stock	$ 383	$ 165	$ 311	$ 350	$ 183	$ 226	$ 860	$ 759
Weighted average common shares outstanding - Basic	292.9			283.0			292.5	282.2
Add: Incremental shares attributable to effect of potentially dilutive securities	1.7			1.6			1.7	1.5
Adjusted weighted average common shares outstanding - Diluted	294.6			284.6			294.2	283.7
Net income for common stock per common share - basic	$ 1.31			$ 1.24			$ 2.94	$ 2.69
Net income for common stock per common share - diluted	$ 1.30			$ 1.23			$ 2.92	$ 2.68

XML

Summary Of Significant Accounting Policies

9 Months Ended

Sep. 30, 2011

Summary Of Significant Accounting Policies

Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

For the three and nine months ended September 30, 2011 and 2010, Con Edison's basic and diluted 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)	2011		2010		2011		2010
Net income for common stock	$	383	$	350	$	860	$	759
Weighted average common shares outstanding – Basic		292.9		283.0		292.5		282.2
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.6		1.7		1.5
Adjusted weighted average common shares outstanding – Diluted		294.6		284.6		294.2		283.7
Net income for common stock per common share – basic	$	1.31	$	1.24	$	2.94	$	2.69
Net income for common stock per common share – diluted	$	1.30	$	1.23	$	2.92	$	2.68

CECONY [Member]

Summary Of Significant Accounting Policies

Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

For the three and nine months ended September 30, 2011 and 2010, Con Edison's basic and diluted 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)	2011		2010		2011		2010
Net income for common stock	$	383	$	350	$	860	$	759
Weighted average common shares outstanding – Basic		292.9		283.0		292.5		282.2
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.6		1.7		1.5
Adjusted weighted average common shares outstanding – Diluted		294.6		284.6		294.2		283.7
Net income for common stock per common share – basic	$	1.31	$	1.24	$	2.94	$	2.69
Net income for common stock per common share – diluted	$	1.30	$	1.23	$	2.92	$	2.68

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Derivative Instruments And Hedging Activities (Narrative) (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2011
Schedule of Investments [Line Items]
Energy supply and hedging activities credit exposure total	$ 120
Makeup of net credit exposure counterparties	60
Makeup of net credit exposure primarily with commodity exchange	44
Independent system operators	15
Number of contracts considered derivatives	1,565
Unrealized gain (loss) on derivatives	(9)
Derivative, fixed interest rate	6.09%
Non-Investment Grade Counterparties [Member]
Schedule of Investments [Line Items]
Makeup of net credit exposure primarily with commodity exchange	$ 1

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Financial Information By Business Segment (Tables)

9 Months Ended

Sep. 30, 2011

Financial Information By Business Segment [Abstract]

Financial Data For The Business Segments

	For the Three Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2011			2010			2011			2010			2011		2010		2011			2010
CECONY
Electric	$	2,644		$	2,570		$	3		$	3		$	166	$	156	$	758		$	715
Gas		197			204			1			1			28		26		(23	)		(16	)
Steam		76			91			20			18			15		16		(33	)		(33	)
Consolidation adjustments		—			—			(24	)		(22	)		—		—		—			—
Total CECONY	$	2,917		$	2,865		$	—		$	—		$	209	$	198	$	702		$	666
O&R
Electric	$	217		$	245		$	—		$	—		$	9	$	8	$	44		$	52
Gas		24			25			—			—			3		3		(6	)		(4	)
Total O&R	$	241		$	270		$	—		$	—		$	12	$	11	$	38		$	48
Competitive energy businesses	$	472		$	584		$	3		$	2		$	1	$	2	$	16		$	(8	)
Other*		(1	)		(12	)		(3	)		(2	)		—		—		—			(1	)
Total Con Edison	$	3,629		$	3,707		$	—		$	—		$	222	$	211	$	756		$	705

* Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

	For the Nine Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2011			2010			2011			2010			2011		2010		2011			2010
CECONY
Electric	$	6,378		$	6,402		$	9		$	9		$	489	$	464	$	1,326		$	1,228
Gas		1,156			1,126			4			4			82		76		212			243
Steam		508			487			59			55			47		46		81			41
Consolidation adjustments		—			—			(72	)		(68	)		—		—		—			—
Total CECONY	$	8,042		$	8,015		$	—		$	—		$	618	$	586	$	1,619		$	1,512
O&R
Electric	$	507		$	559		$	—		$	—		$	26	$	24	$	69		$	71
Gas		153			150			—			—			10		9		22			20
Total O&R	$	660		$	709		$	—		$	—		$	36	$	33	$	91		$	91
Competitive energy businesses	$	1,286		$	1,491		$	9		$	6		$	5	$	7	$	75		$	25
Other*		(16	)		(30	)		(9	)		(6	)		—		—		(2	)		(1	)
Total Con Edison	$	9,972		$	10,185		$	—		$	—		$	659	$	626	$	1,781		$	1,627

* Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

XML

Short-Term Borrowing (Details) (USD $)	9 Months Ended
	Sep. 30, 2011	Dec. 31, 2010
Short-term Debt [Line Items]
Credit facility expiry date	October 2016
Maximum borrowing capacity	$ 2,250,000,000
Current amount available	1,000,000,000
Line of credit facility, covenant terms	ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at September 30, 2011 this ratio was 0.48 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding 5 percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants.
Commercial paper outstanding	0	0
Loans outstanding under Credit Agreement, amount	0	0
Letters of credit outstanding under the credit agreement	223,000,000	197,000,000
Letter Of Credit [Member]
Short-term Debt [Line Items]
Current amount available	$ 1,200,000,000

XML

Financial Information By Business Segment (Financial Data For The Business Segments) (Details) (USD $) In Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2011		Sep. 30, 2010		Sep. 30, 2011		Sep. 30, 2010
Operating revenues	$ 3,629		$ 3,707		$ 9,972		$ 10,185
Depreciation and amortization	222		211		659		626
Operating income	756		705		1,781		1,627
CECONY - Electric [Member]
Operating revenues	2,644		2,570		6,378		6,402
Inter-segment revenues	3		3		9		9
Depreciation and amortization	166		156		489		464
Operating income	758		715		1,326		1,228
CECONY - Gas [Member]
Operating revenues	197		204		1,156		1,126
Inter-segment revenues	1		1		4		4
Depreciation and amortization	28		26		82		76
Operating income	(23)		(16)		212		243
CECONY - Steam [Member]
Operating revenues	76		91		508		487
Inter-segment revenues	20		18		59		55
Depreciation and amortization	15		16		47		46
Operating income	(33)		(33)		81		41
O&R - Electric [Member]
Operating revenues	217		245		507		559
Depreciation and amortization	9		8		26		24
Operating income	44		52		69		71
O&R - Gas [Member]
Operating revenues	24		25		153		150
Depreciation and amortization	3		3		10		9
Operating income	(6)		(4)		22		20
Competitive Energy Businesses [Member]
Operating revenues	472		584		1,286		1,491
Inter-segment revenues	3		2		9		6
Depreciation and amortization	1		2		5		7
Operating income	16		(8)		75		25
Other Revenues And Eliminations In Segment Information [Member]
Operating revenues	(1)	[1]	(12)	[1]	(16)	[1]	(30)	[1]
Inter-segment revenues	(3)	[1]	(2)	[1]	(9)	[1]	(6)	[1]
Operating income			(1)	[1]	(2)	[1]	(1)	[1]
CECONY [Member]
Operating revenues	2,917		2,865		8,042		8,015
Depreciation and amortization	209		198		618		586
Operating income	702		666		1,619		1,512
Consolidation Adjustments [Member]
Inter-segment revenues	(24)		(22)		(72)		(68)
O&R [Member]
Operating revenues	241		270		660		709
Depreciation and amortization	12		11		36		33
Operating income	$ 38		$ 48		$ 91		$ 91

[1] Parent company expenses, primarily interest, and consolidation adjustments. Other does not represent a business segment.

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2011

Fair Value Measurements [Abstract]

Assets And Liabilities Measured At Fair Value On A Recurring Basis

	Level 1				Level 2						Level 3						Netting Adjustments (4)						Total
(Millions of Dollars)	Con Edison		CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity	$	2	$	—	$	52		$	28		$	69		$	17		$	(44	)	$	(6	)	$	79		$	39
Transfer in (5) (6)		1		1		—			—			—			—			—			—			1			1
Transfer out (5) (6)		—		—		(1	)		(1	)		—			—			—			—			(1	)		(1	)
Commodity (1)		3		1		51			27			69			17			(44	)		(6	)		79			39
Other assets (3)		75		75		—			—			100			91			—			—			175			166
Total	$	78	$	76	$	51		$	27		$	169		$	108		$	(44	)	$	(6	)	$	254		$	205
Derivative liabilities:
Commodity	$	10	$	5	$	130		$	91		$	98		$	11		$	(117	)	$	(47	)	$	121		$	60
Transfer in (5) (7)		—		—		23			8			1			1			—			—			24			9
Transfer out (5) (7)		—		—		(1	)		(1	)		(23	)		(8	)		—			—			(24	)		(9	)
Commodity (1)	$	10	$	5	$	152		$	98		$	76		$	4		$	(117	)	$	(47	)	$	121		$	60
Interest rate contract (2)		—		—		—			—			9			—			—			—			9			—
Total	$	10	$	5	$	152		$	98		$	85		$	4		$	(117	)	$	(47	)	$	130		$	60

(1) A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

(2) See Note I.

(3) Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

(4) 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.

(5) The Companies' policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

(6) Transferred from Level 2 to Level 1 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

(7) Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2010 to less than one year as of September 30, 2011.

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2010 are summarized as follows:

	Level 1				Level 2						Level 3						Netting Adjustments (4)						Total
(Millions of Dollars)	Con Edison		CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity (1)	$	2	$	1	$	72		$	21		$	144		$	13		$	(112	)	$	13		$	106		$	48
Other assets (3)		65		64		—			—			101			92			—			—			166			156
Total	$	67	$	65	$	72		$	21		$	245		$	105		$	(112	)	$	13		$	272		$	204
Derivative liabilities:
Commodity	$	4	$	2	$	270		$	177		$	205		$	12		$	(288	)	$	(91	)	$	191		$	100
Transfer in (5) (6) (7)		—		—		(36	)		(36	)		(9	)		(9	)		—			—			(45	)		(45	)
Transfer out (5) (6) (7)		—		—		9			9			36			36			—			—			45			45
Commodity (1)	$	4	$	2	$	243		$	150		$	232		$	39		$	(288	)	$	(91	)	$	191		$	100
Interest rate contract (2)		—		—		—			—			10			—			—			—			10			—
Total	$	4	$	2	$	243		$	150		$	242		$	39		$	(288	)	$	(91	)	$	201		$	100

(1) A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

(2) See Note I.

(3) Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

(4) 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.

(5) The Companies' policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

(6) Transferred from Level 2 to Level 3 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

(7) Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2009 to less than one year as of December 31, 2010.

Reconciliation Of The Beginning And Ending Net Balances For Assets And Liabilities Measured At Level 3 Fair Value

	For the Three Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity	$	(25	)	$	(27	)	$	9		$	8	$	—	$	—	$	4	$	24	$	(7	)
Interest rate contract		(10	)		(1	)		1			—		—		—		1		—		(9	)
Other assets (1)		106			(3	)		(3	)		—		—		—		—		—		100
Total	$	71		$	(31	)	$	7		$	8	$	—	$	—	$	5	$	24	$	84
CECONY
Derivatives:
Commodity	$	—		$	(8	)	$	1		$	8	$	—	$		$	3	$	9	$	13
Other assets (1)		96			(3	)		(2	)		—		—				—		—		91
Total	$	96		$	(11	)	$	(1	)	$	8	$	—	$		$	3	$	9	$	104

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

	For the Nine Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	(5	)	$	54		$	22	$	—	$	—	$	(19	)	$	29	$	(7	)
Interest rate contract		(10	)		(3	)		1			—		—		—		3			—		(9	)
Other assets (1)		101			—			(1	)		—		—		—		—			—		100
Total	$	3		$	(8	)	$	54		$	22	$	—	$	—	$	(16	)	$	29	$	84
CECONY
Derivatives:
Commodity	$	(26	)	$	(11	)	$	22		$	18	$	—	$	—	$	(4	)	$	14	$	13
Other assets (1)		92			—			(1	)		—		—		—		—			—		91
Total	$	66		$	(11	)	$	21		$	18	$	—	$	—	$	(4	)	$	14	$	104

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2010 and classified as Level 3 in the fair value hierarchy below.

	For the Three Months Ended September 30, 2010
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2010			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of September 30, 2010
Con Edison
Derivatives:
Commodity	$	(101	)	$	(34	)	$	(12	)	$	1	$	—	$	—	$	4	$	(2	)	$	(144	)
Interest rate contract		(12	)		—			—			—		—		—		—		—			(12	)
Other assets (1)		94			—			2			—		—		—		—		—			96
Total	$	(19	)	$	(34	)	$	(10	)	$	1	$	—	$	—	$	4	$	(2	)	$	(60	)
CECONY
Derivatives:
Commodity	$	(30	)	$	(7	)	$	(3	)	$	1	$	—	$	—	$	4	$	(2	)	$	(37	)
Other assets (1)		85			—			2			—		—		—		—		—			87
Total	$	55		$	(7	)	$	(1	)	$	1	$	—	$	—	$	4	$	(2	)	$	50

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

	For Nine Months Ended September 30, 2010
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2010			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2010
Con Edison
Derivatives:
Commodity	$	(59	)	$	(68	)	$	(56	)	$	2	$	—	$	—	$	16		$	21	$	(144	)
Interest rate contract		(11	)		(2	)		(1	)		—		—		—		2			—		(12	)
Other assets (1)		92			—			4			—		—		—		—			—		96
Total	$	22		$	(70	)	$	(53	)	$	2	$	—	$	—	$	18		$	21	$	(60	)
CECONY
Derivatives:
Commodity	$	(5	)	$	(14	)	$	(37	)	$	—	$	—	$	—	$	(2	)	$	21	$	(37	)
Other assets (1)		83			—			4			—		—		—		—			—		87
Total	$	78		$	(14	)	$	(33	)	$	—	$	—	$	—	$	(2	)	$	21	$	(50	)

(1) Amounts included in earnings are reported in investment and other income on the consolidated income statement.

XML

Derivative Instruments And Hedging Activities

9 Months Ended

Sep. 30, 2011

Derivative Instruments And Hedging Activities

Note I — Derivative Instruments and Hedging Activities

Under the accounting rules for derivatives and hedging, derivatives are recognized on the balance sheet at fair value, unless an exception is available under the accounting rules. Certain qualifying derivative contracts have been designated as normal purchases or normal sales contracts. These contracts are not reported at fair value under the accounting rules.

Energy Price Hedging

Con Edison's subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, and steam by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. The fair values of these hedges at September 30, 2011 and December 31, 2010 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Fair value of net derivative assets/(liabilities) – gross	$	(115	)	$	(261	)	$	(62	)	$	(156	)
Impact of netting of cash collateral		73			176			41			104
Fair value of net derivative assets/(liabilities) – net	$	(42	)	$	(85	)	$	(21	)	$	(52	)

Credit Exposure

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. 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.

At September 30, 2011, Con Edison and CECONY had $120 million and $24 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison's net credit exposure consisted of $60 million with investment-grade counterparties, $44 million with commodity exchange brokers, $15 million with independent system operators and $1 million with non-investment grade counterparties. CECONY's entire net credit exposure was with commodity exchange brokers.

Economic Hedges

The Companies enter into certain derivative instruments that do not qualify or are not designated as hedges under the accounting rules for derivatives and hedging. However, management believes these instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

The fair values of the Companies' commodity derivatives at September 30, 2011 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets	$	112		$	41
Long-term	Other deferred charges and non-current assets		36			23
Total derivative assets		$	148		$	64
Impact of netting			(68	)		(25	)
Net derivative assets		$	80		$	39
Derivative Liabilities
Current	Fair value of derivative liabilities	$	209		$	95
Long-term	Fair value of derivative liabilities		54			31
Total derivative liabilities		$	263		$	126
Impact of netting			(141	)		(66	)
Net derivative liabilities		$	122		$	60

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

The fair values of the Companies' commodity derivatives at December 31, 2010 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets	$	184		$	29
Long-term	Other deferred charges and non-current assets		51			19
Total derivative assets		$	235		$	48
Impact of netting			(129	)		—
Net derivative assets		$	106		$	48
Derivative Liabilities
Current	Fair value of derivative liabilities	$	385		$	148
Long-term	Fair value of derivative liabilities		111			56
Total derivative liabilities		$	496		$	204
Impact of netting			(305	)		(104	)
Net derivative liabilities		$	191		$	100

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

The Utilities generally recover all of their prudently incurred fuel, purchased power and gas cost, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility commissions. 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 earnings in the reporting period in which they occur.

The following tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2011:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the three months ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(2	)	$	(1	)
Long-term	Regulatory liabilities		1			1
Total deferred gains		$	(1	)	$	—
Current	Deferred derivative losses	$	12		$	7
Current	Recoverable energy costs		(75	)		(53	)
Long-term	Regulatory assets		10			6
Total deferred losses		$	(53	)	$	(40	)
Net deferred losses		$	(54	)	$	(40	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	29	(b)	$	—
	Gas purchased for resale		6			—
	Non-utility revenue		5	(b)		—
Total pre-tax gain/(loss) recognized in income		$	40		$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the three months ended September 30, 2011 Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss) of $(10) million and $(1) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the nine months ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	—		$	—
Long-term	Regulatory liabilities		3			3
Total deferred gains		$	3		$	3
Current	Deferred derivative losses	$	80		$	61
Current	Recoverable energy costs		(177	)		(134	)
Long-term	Regulatory assets		38			27
Total deferred losses		$	(59	)	$	(47	)
Net deferred losses		$	(56	)	$	(44	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	81	(b)	$	—
	Gas purchased for resale		17			—
	Non-utility revenue		22	(b)		—
Total pre-tax gain/(loss) recognized in income		$	120		$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the nine months ended September 30, 2011, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss)/gain of $(35) million and $59 million, respectively.

The following tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2010:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended September 30, 2010
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(3	)	$	(3	)
Total deferred losses		$	(3	)	$	(3	)
Current	Other current assets	$	(61	)	$	(54	)
Current	Recoverable energy costs		(70	)		(63	)
Long term	Regulatory assets		4			7
Total deferred losses		$	(127	)	$	(110	)
Net deferred losses		$	(130	)	$	(113	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(26	)(b)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		4	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(23	)	$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the three months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(3)million and $(34) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 2010
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(8	)	$	(8	)
Total deferred losses		$	(8	)	$	(8	)
Current	Other current assets	$	(127	)	$	(114	)
Current	Recoverable energy costs	$	(205	)	$	(172	)
Long term	Regulatory assets	$	(19	)	$	(11	)
Total deferred losses		$	(351	)	$	(297	)
Net deferred losses		$	(359	)	$	(305	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(132	)(b)	$	—
	Gas purchased for resale		(7	)		—
	Non-utility revenue		21	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(118	)	$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the nine months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(1) million and $(34) million, respectively.

As of September 30, 2011, Con Edison had 1,565 contracts, including 612 CECONY contracts, which were considered to be derivatives under the accounting rules for derivatives and hedging (excluding qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts). The following table presents the number of contracts by commodity type:

	Electric Derivatives								Gas Derivatives
	Number of Energy Contracts (a)		MWHs (b)		Number of Capacity Contracts (a)		MWs (b)		Number of Contracts (a)		Dths (b)		Total Number Of Contracts (a)
Con Edison		810		16,479,730		73		8,201		682		98,382,500		1,565
CECONY		146		4,025,375		—		—		466		90,710,000		612

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) Volumes are reported net of long and short positions.

The Companies also enter into electric congestion and gas basis swap contracts to hedge the congestion and transportation charges which are associated with electric and gas contracts and hedged volumes.

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 the Companies to provide collateral on derivative instruments in net liability positions. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the Companies' credit ratings.

The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position and collateral posted at September 30, 2011, 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 were:

(Millions of Dollars)	Con Edison (a)			CECONY (a)
Aggregate fair value – net liabilities	$	128		$	70
Collateral posted	$	34	(b)	$	29	(b)
Additional collateral (c) (downgrade one level from current ratings (d))	$	11		$	9
Additional collateral (c) (downgrade to below investment grade from current ratings (d))	$	143	(e)	$	54	(e)

(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 Con Edison's competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post collateral, which at September 30, 2011, would have amounted to an estimated $146 million for Con Edison. 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) Across the Utilities' energy derivative positions, credit limits for the same counterparties are generally integrated. At September 30, 2011, the Utilities posted combined collateral of $34 million, including an estimated $5 million attributable to O&R.

(c) 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 of setoff.

(d) The current ratings are Moody's, S&P and Fitch long-term credit rating of, as applicable, Con Edison (Baa1/BBB+/BBB+), CECONY (A3/A-/A-) or O&R (Baa1/A-/A-). Credit ratings assigned by rating agencies are expressions of opinions that are subject to revision or withdrawal at any time by the assigning rating agency.

(e) Derivative instruments that are net assets have been excluded from the table. At September 30, 2011, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of an estimated $16 million.

Interest Rate Swap

O&R has an interest rate swap pursuant to which it pays a fixed-rate of 6.09 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at September 30, 2011 was an unrealized loss of $9 million, which has been included in Con Edison's consolidated balance sheet as a noncurrent liability/fair value of derivative liabilities and a regulatory asset. The increase in the fair value of the swap for the three and nine months ended September 30, 2011 was not material. In the event O&R's credit rating was downgraded to BBB- or lower by S&P or Baa3 or lower by Moody's, the swap counterparty could elect to terminate the agreement and, if it did so, the parties would then be required to settle the transaction.

CECONY [Member]

Derivative Instruments And Hedging Activities

Note I — Derivative Instruments and Hedging Activities

Under the accounting rules for derivatives and hedging, derivatives are recognized on the balance sheet at fair value, unless an exception is available under the accounting rules. Certain qualifying derivative contracts have been designated as normal purchases or normal sales contracts. These contracts are not reported at fair value under the accounting rules.

Energy Price Hedging

Con Edison's subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, and steam by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. The fair values of these hedges at September 30, 2011 and December 31, 2010 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Fair value of net derivative assets/(liabilities) – gross	$	(115	)	$	(261	)	$	(62	)	$	(156	)
Impact of netting of cash collateral		73			176			41			104
Fair value of net derivative assets/(liabilities) – net	$	(42	)	$	(85	)	$	(21	)	$	(52	)

Credit Exposure

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. 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.

At September 30, 2011, Con Edison and CECONY had $120 million and $24 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison's net credit exposure consisted of $60 million with investment-grade counterparties, $44 million with commodity exchange brokers, $15 million with independent system operators and $1 million with non-investment grade counterparties. CECONY's entire net credit exposure was with commodity exchange brokers.

Economic Hedges

The Companies enter into certain derivative instruments that do not qualify or are not designated as hedges under the accounting rules for derivatives and hedging. However, management believes these instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

The fair values of the Companies' commodity derivatives at September 30, 2011 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets	$	112		$	41
Long-term	Other deferred charges and non-current assets		36			23
Total derivative assets		$	148		$	64
Impact of netting			(68	)		(25	)
Net derivative assets		$	80		$	39
Derivative Liabilities
Current	Fair value of derivative liabilities	$	209		$	95
Long-term	Fair value of derivative liabilities		54			31
Total derivative liabilities		$	263		$	126
Impact of netting			(141	)		(66	)
Net derivative liabilities		$	122		$	60

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

The fair values of the Companies' commodity derivatives at December 31, 2010 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets	$	184		$	29
Long-term	Other deferred charges and non-current assets		51			19
Total derivative assets		$	235		$	48
Impact of netting			(129	)		—
Net derivative assets		$	106		$	48
Derivative Liabilities
Current	Fair value of derivative liabilities	$	385		$	148
Long-term	Fair value of derivative liabilities		111			56
Total derivative liabilities		$	496		$	204
Impact of netting			(305	)		(104	)
Net derivative liabilities		$	191		$	100

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

The Utilities generally recover all of their prudently incurred fuel, purchased power and gas cost, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility commissions. 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 earnings in the reporting period in which they occur.

The following tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2011:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the three months ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(2	)	$	(1	)
Long-term	Regulatory liabilities		1			1
Total deferred gains		$	(1	)	$	—
Current	Deferred derivative losses	$	12		$	7
Current	Recoverable energy costs		(75	)		(53	)
Long-term	Regulatory assets		10			6
Total deferred losses		$	(53	)	$	(40	)
Net deferred losses		$	(54	)	$	(40	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	29	(b)	$	—
	Gas purchased for resale		6			—
	Non-utility revenue		5	(b)		—
Total pre-tax gain/(loss) recognized in income		$	40		$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the three months ended September 30, 2011 Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss) of $(10) million and $(1) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the nine months ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	—		$	—
Long-term	Regulatory liabilities		3			3
Total deferred gains		$	3		$	3
Current	Deferred derivative losses	$	80		$	61
Current	Recoverable energy costs		(177	)		(134	)
Long-term	Regulatory assets		38			27
Total deferred losses		$	(59	)	$	(47	)
Net deferred losses		$	(56	)	$	(44	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	81	(b)	$	—
	Gas purchased for resale		17			—
	Non-utility revenue		22	(b)		—
Total pre-tax gain/(loss) recognized in income		$	120		$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the nine months ended September 30, 2011, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss)/gain of $(35) million and $59 million, respectively.

The following tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2010:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended September 30, 2010
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(3	)	$	(3	)
Total deferred losses		$	(3	)	$	(3	)
Current	Other current assets	$	(61	)	$	(54	)
Current	Recoverable energy costs		(70	)		(63	)
Long term	Regulatory assets		4			7
Total deferred losses		$	(127	)	$	(110	)
Net deferred losses		$	(130	)	$	(113	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(26	)(b)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		4	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(23	)	$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the three months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(3)million and $(34) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 2010
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(8	)	$	(8	)
Total deferred losses		$	(8	)	$	(8	)
Current	Other current assets	$	(127	)	$	(114	)
Current	Recoverable energy costs	$	(205	)	$	(172	)
Long term	Regulatory assets	$	(19	)	$	(11	)
Total deferred losses		$	(351	)	$	(297	)
Net deferred losses		$	(359	)	$	(305	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(132	)(b)	$	—
	Gas purchased for resale		(7	)		—
	Non-utility revenue		21	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(118	)	$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the nine months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(1) million and $(34) million, respectively.

As of September 30, 2011, Con Edison had 1,565 contracts, including 612 CECONY contracts, which were considered to be derivatives under the accounting rules for derivatives and hedging (excluding qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts). The following table presents the number of contracts by commodity type:

	Electric Derivatives								Gas Derivatives
	Number of Energy Contracts (a)		MWHs (b)		Number of Capacity Contracts (a)		MWs (b)		Number of Contracts (a)		Dths (b)		Total Number Of Contracts (a)
Con Edison		810		16,479,730		73		8,201		682		98,382,500		1,565
CECONY		146		4,025,375		—		—		466		90,710,000		612

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) Volumes are reported net of long and short positions.

The Companies also enter into electric congestion and gas basis swap contracts to hedge the congestion and transportation charges which are associated with electric and gas contracts and hedged volumes.

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 the Companies to provide collateral on derivative instruments in net liability positions. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the Companies' credit ratings.

The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position and collateral posted at September 30, 2011, 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 were:

(Millions of Dollars)	Con Edison (a)			CECONY (a)
Aggregate fair value – net liabilities	$	128		$	70
Collateral posted	$	34	(b)	$	29	(b)
Additional collateral (c) (downgrade one level from current ratings (d))	$	11		$	9
Additional collateral (c) (downgrade to below investment grade from current ratings (d))	$	143	(e)	$	54	(e)

(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 Con Edison's competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post collateral, which at September 30, 2011, would have amounted to an estimated $146 million for Con Edison. 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) Across the Utilities' energy derivative positions, credit limits for the same counterparties are generally integrated. At September 30, 2011, the Utilities posted combined collateral of $34 million, including an estimated $5 million attributable to O&R.

(c) 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 of setoff.

(d) The current ratings are Moody's, S&P and Fitch long-term credit rating of, as applicable, Con Edison (Baa1/BBB+/BBB+), CECONY (A3/A-/A-) or O&R (Baa1/A-/A-). Credit ratings assigned by rating agencies are expressions of opinions that are subject to revision or withdrawal at any time by the assigning rating agency.

(e) Derivative instruments that are net assets have been excluded from the table. At September 30, 2011, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of an estimated $16 million.

Interest Rate Swap

O&R has an interest rate swap pursuant to which it pays a fixed-rate of 6.09 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at September 30, 2011 was an unrealized loss of $9 million, which has been included in Con Edison's consolidated balance sheet as a noncurrent liability/fair value of derivative liabilities and a regulatory asset. The increase in the fair value of the swap for the three and nine months ended September 30, 2011 was not material. In the event O&R's credit rating was downgraded to BBB- or lower by S&P or Baa3 or lower by Moody's, the swap counterparty could elect to terminate the agreement and, if it did so, the parties would then be required to settle the transaction.

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Regulatory Matters

9 Months Ended

Sep. 30, 2011

Regulatory Matters

Note B — Regulatory Matters

Rate Agreements

O&R — Electric

In June 2011, the NYSPSC adopted an order granting O&R an electric rate increase, effective July 1, 2011, of $26.6 million. The NYSPSC ruling reflects the following major items:

• a weighted average cost of capital of 7.22 percent, reflecting:

• a return on common equity of 9.2 percent, assuming achievement by the company of $825,000 of austerity measures;

• cost of long-term debt of 5.50 percent; and

• common equity ratio of 48 percent.

• continuation of a revenue decoupling mechanism;

• a provision for reconciliation of certain differences in actual average net utility plant to the amount reflected in rates ($718 million) and continuation of rate provisions under which pension and other post-retirement benefit expenses, environmental remediation expenses, tax-exempt debt costs and certain other expenses are reconciled to amounts for those expenses reflected in rates;

• continuation of the rate provisions pursuant to which the company recovers its purchased power costs from customers;

• discontinuation of the provisions under which property taxes were reconciled to amounts reflected in rates;

• discontinuation of the inclusion in rates of funding for the company's annual incentive plan for non-officer management employees;

• continuation of provisions for potential operations penalties of up to $3 million annually if certain customer service and system reliability performance targets are not met; and

• O&R is directed to produce a report detailing its implementation plans for the recommendations made in connection with the NYSPSC's management audit of CECONY, with a forecast of costs to achieve and expected savings.

On July 29, 2011, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective July 1, 2012, of $17.7 million. The filing reflects a return on common equity of 10.75 percent and a common equity ratio of 49.4 percent. Among other things, the filing proposes continuation of the current provisions with respect to recovery from customers of the cost of purchased power and with respect to the deferral of differences between actual expenses allocable to the electric business for pensions and other postretirement benefits, environmental, and research and developmental costs to the amounts for such costs reflected in electric rates. The filing also includes an alternative proposal for a three-year electric rate plan with annual rate increases of $17.6 million effective July 2012, 2013 and 2014. The multi-year filing reflects a return on common equity of 11.25 percent.

Other Regulatory Matters

In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures (see "Investigations of Vendor Payments" in Note G). Pursuant to NYSPSC orders, a portion of the company's revenues (currently, $249 million, $32 million and $6 million on an annual basis for electric, gas and steam service, respectively) is being collected subject to potential refund to customers. At September 30, 2011, the company had collected an estimated $753 million from customers subject to potential refund in connection with this proceeding. In October 2010, a NYSPSC consultant reported its $21 million provisional assessment, which the company has disputed, of potential overcharges for construction work. The potential overcharges related to transactions that involved certain employees who were arrested and a contractor that performed work for the company. The NYSPSC's consultant is expected to continue to review the company's expenditures. At September 30, 2011, the company had a $10.5 million regulatory liability relating to this matter. The company is unable to estimate the amount, if any, by which any refund required by the NYSPSC may exceed this regulatory liability.

In February 2011, the NYSPSC initiated a proceeding to examine the existing mechanisms pursuant to which utilities recover site investigation and remediation costs and possible alternatives. See Note F to the Third Quarter Financial Statements.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at September 30, 2011 and December 31, 2010 were comprised of the following items:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Regulatory assets
Unrecognized pension and other postretirement costs	$	3,769	$	4,371	$	3,584	$	4,152
Future federal income tax		1,763		1,593		1,688		1,515
Environmental remediation costs		681		695		563		574
Pension and other post retirement benefits deferrals		198		138		156		90
Revenue taxes		160		145		155		140
Surcharge for New York State assessment		150		121		138		112
Net electric deferrals		126		156		126		156
Deferred storm costs		81		57		61		43
O&R transition bond charges		45		48		—		—
Deferred derivative losses – long-term		34		74		21		48
Workers' compensation		25		31		24		31
Accrued unbilled revenues		22		—		22		—
Property tax reconciliation		12		34		—		27
World Trade Center restoration costs		9		45		9		45
Recoverable energy cost		2		42		2		42
Other		129		133		119		122
Regulatory assets – long-term		7,206		7,683		6,668		7,097
Deferred derivative losses – current		110		190		90		151
Recoverable energy costs – current		—		13		—		—
Regulatory assets – current		110		203		90		151
Total Regulatory Assets	$	7,316	$	7,886	$	6,758	$	7,248
Regulatory liabilities
Allowance for cost of removal less salvage	$	440	$	422	$	365	$	350
World Trade Center settlement proceeds		62		—		62		—
Carrying charges on transmission and distribution net plant		39		28		12		5
Bonus depreciation		24		1		23		1
Energy efficiency programs		23		12		21		11
Gas line losses		21		—		21		—
New York State tax refund		20		30		20		30
Gain on sale of properties		14		28		14		28
Expenditure prudence proceeding		11		—		11		—
Other		167		131		157		122
Regulatory liabilities – long-term		821		652		706		547
Net unbilled revenue deferrals – current		116		136		115		135
Revenue decoupling mechanism		99		38		99		38
Refundable energy cost – current		38		117		13		91
Deferred derivative gains – current		4		4		3		3
Regulatory liabilities – current		257		295		230		267
Total Regulatory Liabilities	$	1,078	$	947	$	936	$	814

CECONY [Member]

Regulatory Matters

Note B — Regulatory Matters

Rate Agreements

O&R — Electric

In June 2011, the NYSPSC adopted an order granting O&R an electric rate increase, effective July 1, 2011, of $26.6 million. The NYSPSC ruling reflects the following major items:

• a weighted average cost of capital of 7.22 percent, reflecting:

• a return on common equity of 9.2 percent, assuming achievement by the company of $825,000 of austerity measures;

• cost of long-term debt of 5.50 percent; and

• common equity ratio of 48 percent.

• continuation of a revenue decoupling mechanism;

• a provision for reconciliation of certain differences in actual average net utility plant to the amount reflected in rates ($718 million) and continuation of rate provisions under which pension and other post-retirement benefit expenses, environmental remediation expenses, tax-exempt debt costs and certain other expenses are reconciled to amounts for those expenses reflected in rates;

• continuation of the rate provisions pursuant to which the company recovers its purchased power costs from customers;

• discontinuation of the provisions under which property taxes were reconciled to amounts reflected in rates;

• discontinuation of the inclusion in rates of funding for the company's annual incentive plan for non-officer management employees;

• continuation of provisions for potential operations penalties of up to $3 million annually if certain customer service and system reliability performance targets are not met; and

• O&R is directed to produce a report detailing its implementation plans for the recommendations made in connection with the NYSPSC's management audit of CECONY, with a forecast of costs to achieve and expected savings.

On July 29, 2011, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective July 1, 2012, of $17.7 million. The filing reflects a return on common equity of 10.75 percent and a common equity ratio of 49.4 percent. Among other things, the filing proposes continuation of the current provisions with respect to recovery from customers of the cost of purchased power and with respect to the deferral of differences between actual expenses allocable to the electric business for pensions and other postretirement benefits, environmental, and research and developmental costs to the amounts for such costs reflected in electric rates. The filing also includes an alternative proposal for a three-year electric rate plan with annual rate increases of $17.6 million effective July 2012, 2013 and 2014. The multi-year filing reflects a return on common equity of 11.25 percent.

Other Regulatory Matters

In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures (see "Investigations of Vendor Payments" in Note G). Pursuant to NYSPSC orders, a portion of the company's revenues (currently, $249 million, $32 million and $6 million on an annual basis for electric, gas and steam service, respectively) is being collected subject to potential refund to customers. At September 30, 2011, the company had collected an estimated $753 million from customers subject to potential refund in connection with this proceeding. In October 2010, a NYSPSC consultant reported its $21 million provisional assessment, which the company has disputed, of potential overcharges for construction work. The potential overcharges related to transactions that involved certain employees who were arrested and a contractor that performed work for the company. The NYSPSC's consultant is expected to continue to review the company's expenditures. At September 30, 2011, the company had a $10.5 million regulatory liability relating to this matter. The company is unable to estimate the amount, if any, by which any refund required by the NYSPSC may exceed this regulatory liability.

In February 2011, the NYSPSC initiated a proceeding to examine the existing mechanisms pursuant to which utilities recover site investigation and remediation costs and possible alternatives. See Note F to the Third Quarter Financial Statements.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at September 30, 2011 and December 31, 2010 were comprised of the following items:

	Con Edison				CECONY
(Millions of Dollars)	2011		2010		2011		2010
Regulatory assets
Unrecognized pension and other postretirement costs	$	3,769	$	4,371	$	3,584	$	4,152
Future federal income tax		1,763		1,593		1,688		1,515
Environmental remediation costs		681		695		563		574
Pension and other post retirement benefits deferrals		198		138		156		90
Revenue taxes		160		145		155		140
Surcharge for New York State assessment		150		121		138		112
Net electric deferrals		126		156		126		156
Deferred storm costs		81		57		61		43
O&R transition bond charges		45		48		—		—
Deferred derivative losses – long-term		34		74		21		48
Workers' compensation		25		31		24		31
Accrued unbilled revenues		22		—		22		—
Property tax reconciliation		12		34		—		27
World Trade Center restoration costs		9		45		9		45
Recoverable energy cost		2		42		2		42
Other		129		133		119		122
Regulatory assets – long-term		7,206		7,683		6,668		7,097
Deferred derivative losses – current		110		190		90		151
Recoverable energy costs – current		—		13		—		—
Regulatory assets – current		110		203		90		151
Total Regulatory Assets	$	7,316	$	7,886	$	6,758	$	7,248
Regulatory liabilities
Allowance for cost of removal less salvage	$	440	$	422	$	365	$	350
World Trade Center settlement proceeds		62		—		62		—
Carrying charges on transmission and distribution net plant		39		28		12		5
Bonus depreciation		24		1		23		1
Energy efficiency programs		23		12		21		11
Gas line losses		21		—		21		—
New York State tax refund		20		30		20		30
Gain on sale of properties		14		28		14		28
Expenditure prudence proceeding		11		—		11		—
Other		167		131		157		122
Regulatory liabilities – long-term		821		652		706		547
Net unbilled revenue deferrals – current		116		136		115		135
Revenue decoupling mechanism		99		38		99		38
Refundable energy cost – current		38		117		13		91
Deferred derivative gains – current		4		4		3		3
Regulatory liabilities – current		257		295		230		267
Total Regulatory Liabilities	$	1,078	$	947	$	936	$	814

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Summary Of Significant Accounting Policies (Policy)

9 Months Ended

Sep. 30, 2011

Summary Of Significant Accounting Policies [Abstract]

Earnings Per Common Share

Earnings Per Common Share

For the three and nine months ended September 30, 2011 and 2010, Con Edison's basic and diluted 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)	2011		2010		2011		2010
Net income for common stock	$	383	$	350	$	860	$	759
Weighted average common shares outstanding – Basic		292.9		283.0		292.5		282.2
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.6		1.7		1.5
Adjusted weighted average common shares outstanding – Diluted		294.6		284.6		294.2		283.7
Net income for common stock per common share – basic	$	1.31	$	1.24	$	2.94	$	2.69
Net income for common stock per common share – diluted	$	1.30	$	1.23	$	2.92	$	2.68

XML

Other Material Contingencies (Narrative) (Details) (USD $) In Millions	9 Months Ended
	Sep. 30, 2011	Dec. 31, 2010
Guarantor Obligations [Line Items]
Lease in lease out total investment	$ 259
Lease in lease out total financed by equity	93
Lease in lease out total financed by long-term debt	166
The company's investment in leverage leases	(52)	(41)
Gross investment in leverage leases	234	235
Deferred tax liabilities	286	276
Tax savings from lease in lease out transactions	232
Total guarantees, by type and term	862	859
Maximum exposure	5
Tax Deficiency Paid In December 2005 [Member]
Guarantor Obligations [Line Items]
Tax deficiency paid to IRS	0.3
Interest In April 2006 [Member]
Guarantor Obligations [Line Items]
Interest paid related to tax deficiency	0.2
Interest Up To March 2011 [Member]
Guarantor Obligations [Line Items]
Interest paid related to tax deficiency	86.0
Disallowance Of Tax 1998-2007 [Member]
Guarantor Obligations [Line Items]
Disallowed deduction	416
Disallowance Of Tax 2010 [Member]
Guarantor Obligations [Line Items]
Disallowed deduction	40
Disallowance Of Tax 2009 [Member]
Guarantor Obligations [Line Items]
Disallowed deduction	41
Disallowance Of Tax 2008 [Member]
Guarantor Obligations [Line Items]
Disallowed deduction	$ 42

XML

Derivative Instruments And Hedging Activities (Tables)

9 Months Ended

Sep. 30, 2011

Derivative Instruments And Hedging Activities [Abstract]

Energy Price Hedging Fair Values

	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Fair value of net derivative assets/(liabilities) – gross	$	(115	)	$	(261	)	$	(62	)	$	(156	)
Impact of netting of cash collateral		73			176			41			104
Fair value of net derivative assets/(liabilities) – net	$	(42	)	$	(85	)	$	(21	)	$	(52	)

Fair Values Of The Companies' Commodity Derivatives

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets	$	112		$	41
Long-term	Other deferred charges and non-current assets		36			23
Total derivative assets		$	148		$	64
Impact of netting			(68	)		(25	)
Net derivative assets		$	80		$	39
Derivative Liabilities
Current	Fair value of derivative liabilities	$	209		$	95
Long-term	Fair value of derivative liabilities		54			31
Total derivative liabilities		$	263		$	126
Impact of netting			(141	)		(66	)
Net derivative liabilities		$	122		$	60

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

The fair values of the Companies' commodity derivatives at December 31, 2010 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets	$	184		$	29
Long-term	Other deferred charges and non-current assets		51			19
Total derivative assets		$	235		$	48
Impact of netting			(129	)		—
Net derivative assets		$	106		$	48
Derivative Liabilities
Current	Fair value of derivative liabilities	$	385		$	148
Long-term	Fair value of derivative liabilities		111			56
Total derivative liabilities		$	496		$	204
Impact of netting			(305	)		(104	)
Net derivative liabilities		$	191		$	100

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

Changes In The Fair Values Of Commodity Derivatives

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the three months ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(2	)	$	(1	)
Long-term	Regulatory liabilities		1			1
Total deferred gains		$	(1	)	$	—
Current	Deferred derivative losses	$	12		$	7
Current	Recoverable energy costs		(75	)		(53	)
Long-term	Regulatory assets		10			6
Total deferred losses		$	(53	)	$	(40	)
Net deferred losses		$	(54	)	$	(40	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	29	(b)	$	—
	Gas purchased for resale		6			—
	Non-utility revenue		5	(b)		—
Total pre-tax gain/(loss) recognized in income		$	40		$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the three months ended September 30, 2011 Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss) of $(10) million and $(1) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the nine months ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	—		$	—
Long-term	Regulatory liabilities		3			3
Total deferred gains		$	3		$	3
Current	Deferred derivative losses	$	80		$	61
Current	Recoverable energy costs		(177	)		(134	)
Long-term	Regulatory assets		38			27
Total deferred losses		$	(59	)	$	(47	)
Net deferred losses		$	(56	)	$	(44	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	81	(b)	$	—
	Gas purchased for resale		17			—
	Non-utility revenue		22	(b)		—
Total pre-tax gain/(loss) recognized in income		$	120		$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the nine months ended September 30, 2011, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss)/gain of $(35) million and $59 million, respectively.

The following tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2010:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended September 30, 2010
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(3	)	$	(3	)
Total deferred losses		$	(3	)	$	(3	)
Current	Other current assets	$	(61	)	$	(54	)
Current	Recoverable energy costs		(70	)		(63	)
Long term	Regulatory assets		4			7
Total deferred losses		$	(127	)	$	(110	)
Net deferred losses		$	(130	)	$	(113	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(26	)(b)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		4	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(23	)	$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the three months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(3)million and $(34) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 2010
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(8	)	$	(8	)
Total deferred losses		$	(8	)	$	(8	)
Current	Other current assets	$	(127	)	$	(114	)
Current	Recoverable energy costs	$	(205	)	$	(172	)
Long term	Regulatory assets	$	(19	)	$	(11	)
Total deferred losses		$	(351	)	$	(297	)
Net deferred losses		$	(359	)	$	(305	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(132	)(b)	$	—
	Gas purchased for resale		(7	)		—
	Non-utility revenue		21	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(118	)	$	—

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) For the nine months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(1) million and $(34) million, respectively.

Number Of Derivative Contracts By Commodity Type

	Electric Derivatives								Gas Derivatives
	Number of Energy Contracts (a)		MWHs (b)		Number of Capacity Contracts (a)		MWs (b)		Number of Contracts (a)		Dths (b)		Total Number Of Contracts (a)
Con Edison		810		16,479,730		73		8,201		682		98,382,500		1,565
CECONY		146		4,025,375		—		—		466		90,710,000		612

(a) Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

(b) Volumes are reported net of long and short positions.

Aggregate Fair Value Of All Derivative Instruments With Credit Risk Related Contingent Features

(Millions of Dollars)	Con Edison (a)			CECONY (a)
Aggregate fair value – net liabilities	$	128		$	70
Collateral posted	$	34	(b)	$	29	(b)
Additional collateral (c) (downgrade one level from current ratings (d))	$	11		$	9
Additional collateral (c) (downgrade to below investment grade from current ratings (d))	$	143	(e)	$	54	(e)

(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 Con Edison's competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post collateral, which at September 30, 2011, would have amounted to an estimated $146 million for Con Edison. 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) Across the Utilities' energy derivative positions, credit limits for the same counterparties are generally integrated. At September 30, 2011, the Utilities posted combined collateral of $34 million, including an estimated $5 million attributable to O&R.

(c) 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 of setoff.

(d) The current ratings are Moody's, S&P and Fitch long-term credit rating of, as applicable, Con Edison (Baa1/BBB+/BBB+), CECONY (A3/A-/A-) or O&R (Baa1/A-/A-). Credit ratings assigned by rating agencies are expressions of opinions that are subject to revision or withdrawal at any time by the assigning rating agency.

(e) Derivative instruments that are net assets have been excluded from the table. At September 30, 2011, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of an estimated $16 million.

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Consolidated Balance Sheet (Parenthetical) (USD $) In Millions	Sep. 30, 2011	Dec. 31, 2010
Accounts receivable - customers, allowance for uncollectible accounts	$ 88	$ 76
Other receivables, allowance for uncollectible accounts	9	8
Non-utility property, accumulated depreciation	57	51
Intangible assets, accumulated amortization	3	3
CECONY [Member]
Accounts receivable - customers, allowance for uncollectible accounts	80	68
Other receivables, allowance for uncollectible accounts	8	7
Non-utility property, accumulated depreciation	$ 23	$ 22

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Summary Of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2011

Summary Of Significant Accounting Policies [Abstract]

Earnings Per Common Share

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2011		2010		2011		2010
Net income for common stock	$	383	$	350	$	860	$	759
Weighted average common shares outstanding – Basic		292.9		283.0		292.5		282.2
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.6		1.7		1.5
Adjusted weighted average common shares outstanding – Diluted		294.6		284.6		294.2		283.7
Net income for common stock per common share – basic	$	1.31	$	1.24	$	2.94	$	2.69
Net income for common stock per common share – diluted	$	1.30	$	1.23	$	2.92	$	2.68

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Derivative Instruments And Hedging Activities (Fair Values Of The Companies' Commodity Derivatives) (Details) (USD $) In Millions	Sep. 30, 2011		Dec. 31, 2010
Derivatives, Fair Value [Line Items]
Fair value of derivative assets	$ 148	[1]	$ 235	[1]
Net derivatives asset	80	[1]	106	[1]
Fair value of derivative liabilities	263	[1]	496	[1]
Net derivatives liability	122	[1]	191	[1]
Derivative Asset [Member]
Derivatives, Fair Value [Line Items]
Impact of netting	(68)	[1]	(129)	[1]
Derivative Asset [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative assets	112	[1]	184	[1]
Derivative Asset [Member] | Other Deferred Charges And Non-Current Assets [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative assets	36	[1]	51	[1]
Derivative Liability [Member]
Derivatives, Fair Value [Line Items]
Impact of netting	(141)	[1]	(305)	[1]
Derivative Liability [Member] | Fair Value Of Derivative Liabilities, Current [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative liabilities	209	[1]	385	[1]
Derivative Liability [Member] | Fair Value Of Derivative Liabilities, Long Term [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative liabilities	$ 54	[1]	$ 111	[1]

[1] Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

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Pension Benefits (Tables) (Pension Benefits [Member])

9 Months Ended

Sep. 30, 2011

Pension Benefits [Member]

Net Periodic Pension Benefit Costs

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost – including administrative expenses	$	48		$	42		$	45		$	39
Interest cost on projected benefit obligation		140			139			131			130
Expected return on plan assets		(184	)		(175	)		(174	)		(167	)
Amortization of net actuarial loss		133			106			126			100
Amortization of prior service costs		2			2			—			2
NET PERIODIC BENEFIT COST	$	139		$	114		$	128		$	104
Amortization of regulatory asset		—			—			—			—
TOTAL PERIODIC BENEFIT COST	$	139		$	114		$	128		$	104
Cost capitalized		(45	)		(40	)		(42	)		(36	)
Cost deferred		(11	)		(29	)		(11	)		(29	)
Cost charged to operating expenses	$	83		$	45		$	75		$	39
	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2011			2010			2011			2010
Service cost – including administrative expenses	$	142		$	126		$	133		$	117
Interest cost on projected benefit obligation		420			417			393			390
Expected return on plan assets		(550	)		(527	)		(524	)		(501	)
Amortization of net actuarial loss		397			318			376			300
Amortization of prior service costs		6			6			4			6
NET PERIODIC BENEFIT COST	$	415		$	340		$	382		$	312
Amortization of regulatory asset*		1			1			1			1
TOTAL PERIODIC BENEFIT COST	$	416		$	341		$	383		$	313
Cost capitalized		(141	)		(118	)		(131	)		(109	)
Cost deferred		(68	)		(85	)		(70	)		(82	)
Cost charged to operating expenses	$	207		$	138		$	182		$	122

* Relates to increases in CECONY's pension obligations of $45 million from a 1999 special retirement program.

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Consolidated Statement Of Comprehensive Income (Parenthetical) (USD $) In Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Consolidated Statement Of Comprehensive Income [Abstract]
Pension plan liability adjustments, taxes	$ 1	$ 1	$ 4	$ 4

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Other Material Contingencies

9 Months Ended

Sep. 30, 2011

Other Material Contingencies

Note G — 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 100 suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for personal injury, property damage and business interruption. The company has not accrued a liability for the suits. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover most of the company's costs, which the company is unable to estimate, but which could be substantial, to satisfy its liability to others in connection with the incident.

Investigations of Vendor Payments

In January 2009, CECONY commenced an internal investigation relating to the arrests of certain employees and retired employees (all of whom have since been convicted) for accepting kickbacks from contractors that performed construction work for the company. The company has retained a law firm, which has retained an accounting firm, to assist in the company's investigation. The company has provided information to governmental authorities, which consider the company to be a victim of unlawful conduct, in connection with their investigation of the arrested employees and contractors. The company has terminated its employment of the arrested employees and its contracts with the contractors. In February 2009, the NYSPSC commenced a proceeding that, among other things, will examine the prudence of certain of the company's expenditures relating to the arrests and consider whether additional expenditures should also be examined (see "Other Regulatory Matters" in Note B).

CECONY is also investigating the September 2010 arrest of a retired employee (who has since pleaded guilty to participating in a bribery scheme in which the employee received payments from two companies that supplied materials to the company) and the January 2011 arrest of an employee (for accepting kickbacks from an engineering firm that performed work for the

company). CECONY has provided information to governmental authorities in connection with their ongoing investigations of these matters.

The company, based upon its evaluation of its internal controls for 2010 and previous years, believes that the controls were effective to provide reasonable assurance that its financial statements have been fairly presented, in all material respects, in conformity with generally accepted accounting principles. Because the company's investigations are ongoing, the company is unable to predict the impact of any of the employees' unlawful conduct on the company's internal controls, business, results of operations or financial position.

Lease In/Lease Out Transactions

In each of 1997 and 1999, Con Edison Development entered into a transaction in which it leased property and then immediately subleased it back to the lessor (termed "Lease In/Lease Out," or LILO transactions). The transactions respectively involve electric generating and gas distribution facilities in the Netherlands, with a total investment of $259 million. The transactions were financed with $93 million of equity and $166 million of non-recourse, long-term debt secured by the underlying assets. In accordance with the accounting rules for leases, Con Edison is accounting for the two LILO transactions as leveraged leases. Accordingly, the company's investment in these leases, net of non-recourse debt, is carried as a single amount in Con Edison's consolidated balance sheet and income is recognized pursuant to a method that incorporates a level rate of return for those years when net investment in the lease is positive, based upon the after-tax cash flows projected at the inception of the leveraged leases. The company's investment in these leveraged leases was $(52) million at September 30, 2011 and $(41) million at December 31, 2010 and is comprised of a $234 million gross investment less $286 million deferred tax liabilities at September 30, 2011 and $235 million gross investment less $276 million of deferred tax liabilities at December 31, 2010.

On audit of Con Edison's tax return for 1997, the IRS disallowed the tax losses in connection with the 1997 LILO transaction. In December 2005, Con Edison paid a $0.3 million income tax deficiency asserted by the IRS for the tax year 1997 with respect to the 1997 LILO transaction. In April 2006, the company paid interest of $0.2 million associated with the deficiency and commenced an action in the United States Court of Federal Claims, entitled Consolidated Edison Company of New York, Inc. v. United States, to obtain a refund of this tax payment and interest. A trial was completed in November 2007. In October 2009, the court issued a decision in favor of the company concluding that the 1997 LILO transaction was, in substance, a true lease that possessed economic substance, the loans relating to the lease constituted bona fide indebtedness, and the deductions for the 1997 LILO transactions claimed by the company in its 1997 federal income tax return are allowable. The IRS is entitled to appeal the decision.

In connection with its audit of Con Edison's federal income tax returns for 1998 through 2007, the IRS disallowed $416 million of net tax deductions taken with respect to both of the LILO transactions for the tax years. Con Edison is pursuing administrative appeals of these audit level disallowances. In connection with its audit of Con Edison's federal income tax returns for 2010, 2009 and 2008, the IRS has disallowed $40 million, $41 million and $42 million, respectively, of net tax deductions taken with respect to both of the LILO transactions. When these audit level disallowances become appealable, Con Edison intends to file an appeal of the disallowances.

Con Edison believes that its LILO transactions have been correctly reported, and has not recorded any reserve with respect to the disallowance of tax losses, or related interest, in connection with its LILO transactions. Con Edison's estimated tax savings, reflected in its financial statements, from the two LILO transactions through September 30, 2011, in the aggregate, was $232 million. If Con Edison were required to repay all or a portion of these amounts, it would also be required to pay interest of up to $86 million net of tax at September 30, 2011.

Pursuant to the accounting rules for leveraged lease transactions, the expected timing of income tax cash flows generated by Con Edison's LILO transactions are required to be reviewed at least annually. If the expected timing of the cash flows is revised, the rate of return and the allocation of income would be recalculated from the inception of the LILO transactions, and the company would be required to recalculate the accounting effect of the LILO transactions, which would result in a charge to earnings that could have a material adverse effect on the company's results of operations.

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 $862 million and $859 million at September 30, 2011 and December 31, 2010, respectively.

A summary, by type and term, of Con Edison's total guarantees at September 30, 2011 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	652	$	3	$	153	$	808
Intra-company guarantees		15		—		1		16
Other guarantees		25		13		—		38
TOTAL	$	692	$	16	$	154	$	862

Energy Transactions — Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in gas, pipeline capacity, transportation, oil, electricity 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.

Intra-company Guarantees — Con Edison guarantees electricity sales made by Con Edison Energy and Con Edison Solutions to O&R and CECONY.

Other Guarantees — Con Edison, also guarantees the following:

• $13 million relates to a guarantee issued by Con Edison to CECONY covering a former Con Edison subsidiary's lease payments to use CECONY's conduit system in accordance with a tariff approved by the NYSPSC and a guarantee issued by Con Edison to a landlord to guarantee the former subsidiary's obligations under a building lease. The former subsidiary is obligated to reimburse Con Edison for any payments made under these guarantees. This obligation is fully secured by letters of credit;

• $25 million for guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects performed by Con Edison Solutions; and

• Con Edison, on behalf of Con Edison Solutions, as a retail electric provider, issued a guarantee to the Public Utility Commission of Texas with no specified limitation on the amount guaranteed, covering the payment of all obligations of a retail electric provider. Con Edison's estimate of the maximum potential obligation is $5 million as of September 30, 2011.

CECONY [Member]

Other Material Contingencies

Note G — 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 100 suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for personal injury, property damage and business interruption. The company has not accrued a liability for the suits. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover most of the company's costs, which the company is unable to estimate, but which could be substantial, to satisfy its liability to others in connection with the incident.

Investigations of Vendor Payments

In January 2009, CECONY commenced an internal investigation relating to the arrests of certain employees and retired employees (all of whom have since been convicted) for accepting kickbacks from contractors that performed construction work for the company. The company has retained a law firm, which has retained an accounting firm, to assist in the company's investigation. The company has provided information to governmental authorities, which consider the company to be a victim of unlawful conduct, in connection with their investigation of the arrested employees and contractors. The company has terminated its employment of the arrested employees and its contracts with the contractors. In February 2009, the NYSPSC commenced a proceeding that, among other things, will examine the prudence of certain of the company's expenditures relating to the arrests and consider whether additional expenditures should also be examined (see "Other Regulatory Matters" in Note B).

CECONY is also investigating the September 2010 arrest of a retired employee (who has since pleaded guilty to participating in a bribery scheme in which the employee received payments from two companies that supplied materials to the company) and the January 2011 arrest of an employee (for accepting kickbacks from an engineering firm that performed work for the

company). CECONY has provided information to governmental authorities in connection with their ongoing investigations of these matters.

The company, based upon its evaluation of its internal controls for 2010 and previous years, believes that the controls were effective to provide reasonable assurance that its financial statements have been fairly presented, in all material respects, in conformity with generally accepted accounting principles. Because the company's investigations are ongoing, the company is unable to predict the impact of any of the employees' unlawful conduct on the company's internal controls, business, results of operations or financial position.

Lease In/Lease Out Transactions

In each of 1997 and 1999, Con Edison Development entered into a transaction in which it leased property and then immediately subleased it back to the lessor (termed "Lease In/Lease Out," or LILO transactions). The transactions respectively involve electric generating and gas distribution facilities in the Netherlands, with a total investment of $259 million. The transactions were financed with $93 million of equity and $166 million of non-recourse, long-term debt secured by the underlying assets. In accordance with the accounting rules for leases, Con Edison is accounting for the two LILO transactions as leveraged leases. Accordingly, the company's investment in these leases, net of non-recourse debt, is carried as a single amount in Con Edison's consolidated balance sheet and income is recognized pursuant to a method that incorporates a level rate of return for those years when net investment in the lease is positive, based upon the after-tax cash flows projected at the inception of the leveraged leases. The company's investment in these leveraged leases was $(52) million at September 30, 2011 and $(41) million at December 31, 2010 and is comprised of a $234 million gross investment less $286 million deferred tax liabilities at September 30, 2011 and $235 million gross investment less $276 million of deferred tax liabilities at December 31, 2010.

On audit of Con Edison's tax return for 1997, the IRS disallowed the tax losses in connection with the 1997 LILO transaction. In December 2005, Con Edison paid a $0.3 million income tax deficiency asserted by the IRS for the tax year 1997 with respect to the 1997 LILO transaction. In April 2006, the company paid interest of $0.2 million associated with the deficiency and commenced an action in the United States Court of Federal Claims, entitled Consolidated Edison Company of New York, Inc. v. United States, to obtain a refund of this tax payment and interest. A trial was completed in November 2007. In October 2009, the court issued a decision in favor of the company concluding that the 1997 LILO transaction was, in substance, a true lease that possessed economic substance, the loans relating to the lease constituted bona fide indebtedness, and the deductions for the 1997 LILO transactions claimed by the company in its 1997 federal income tax return are allowable. The IRS is entitled to appeal the decision.

In connection with its audit of Con Edison's federal income tax returns for 1998 through 2007, the IRS disallowed $416 million of net tax deductions taken with respect to both of the LILO transactions for the tax years. Con Edison is pursuing administrative appeals of these audit level disallowances. In connection with its audit of Con Edison's federal income tax returns for 2010, 2009 and 2008, the IRS has disallowed $40 million, $41 million and $42 million, respectively, of net tax deductions taken with respect to both of the LILO transactions. When these audit level disallowances become appealable, Con Edison intends to file an appeal of the disallowances.

Con Edison believes that its LILO transactions have been correctly reported, and has not recorded any reserve with respect to the disallowance of tax losses, or related interest, in connection with its LILO transactions. Con Edison's estimated tax savings, reflected in its financial statements, from the two LILO transactions through September 30, 2011, in the aggregate, was $232 million. If Con Edison were required to repay all or a portion of these amounts, it would also be required to pay interest of up to $86 million net of tax at September 30, 2011.

Pursuant to the accounting rules for leveraged lease transactions, the expected timing of income tax cash flows generated by Con Edison's LILO transactions are required to be reviewed at least annually. If the expected timing of the cash flows is revised, the rate of return and the allocation of income would be recalculated from the inception of the LILO transactions, and the company would be required to recalculate the accounting effect of the LILO transactions, which would result in a charge to earnings that could have a material adverse effect on the company's results of operations.

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 $862 million and $859 million at September 30, 2011 and December 31, 2010, respectively.

A summary, by type and term, of Con Edison's total guarantees at September 30, 2011 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	652	$	3	$	153	$	808
Intra-company guarantees		15		—		1		16
Other guarantees		25		13		—		38
TOTAL	$	692	$	16	$	154	$	862

Energy Transactions — Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in gas, pipeline capacity, transportation, oil, electricity 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.

Intra-company Guarantees — Con Edison guarantees electricity sales made by Con Edison Energy and Con Edison Solutions to O&R and CECONY.

Other Guarantees — Con Edison, also guarantees the following:

• $13 million relates to a guarantee issued by Con Edison to CECONY covering a former Con Edison subsidiary's lease payments to use CECONY's conduit system in accordance with a tariff approved by the NYSPSC and a guarantee issued by Con Edison to a landlord to guarantee the former subsidiary's obligations under a building lease. The former subsidiary is obligated to reimburse Con Edison for any payments made under these guarantees. This obligation is fully secured by letters of credit;

• $25 million for guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects performed by Con Edison Solutions; and

• Con Edison, on behalf of Con Edison Solutions, as a retail electric provider, issued a guarantee to the Public Utility Commission of Texas with no specified limitation on the amount guaranteed, covering the payment of all obligations of a retail electric provider. Con Edison's estimate of the maximum potential obligation is $5 million as of September 30, 2011.

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Pension Benefits (Net Periodic Pension Benefit Costs) (Details) (USD $) In Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010	Dec. 31, 2011
Companies [Member] | Non-Qualified Supplemental Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Non-qualified supplement pension plan, funded	$ 11		$ 11
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	48	42	142	126
Interest cost on projected benefit obligation	140	139	420	417
Expected return on plan assets	(184)	(175)	(550)	(527)
Amortization of net actuarial loss	133	106	397	318
Amortization of prior service costs	2	2	6	6
NET PERIODIC BENEFIT COST	139	114	415	340
Amortization of regulatory asset			1	1
TOTAL PERIODIC BENEFIT COST	139	114	416	341
Cost capitalized	(45)	(40)	(141)	(118)
Cost deferred	(11)	(29)	(68)	(85)
Cost charged to operating expenses	83	45	207	138
Estimated future employer contributions		$ 434		$ 434	$ 533

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New Financial Accounting Standards

9 Months Ended

Sep. 30, 2011

New Financial Accounting Standards

Note K — New Financial Accounting Standards

In May 2011, the Financial Accounting Standards Board (FASB) issued amendments to the guidance for fair value measurement through Accounting Standards Update (ASU) No. 2011-04, "Fair Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs." The amendments expand Accounting Standards Codification 820's existing disclosure requirements for fair value measurements and makes other amendments. Many of these amendments were made to eliminate unnecessary wording differences between U.S. generally accepted accounting principles and International Financial Reporting Standards. For public entities, the amendments are effective prospectively during interim and annual periods beginning after December 15, 2011. The application of this guidance is not expected to have a material impact on the companies' financial position, results of operations and liquidity.

In June 2011, the FASB issued new guidance for presentation of comprehensive income through ASU No. 2011-05, "Comprehensive Income (Topic 220): Presentation of Comprehensive Income." The amendments require that the comprehensive income be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. In the two-statement approach, the first statement should present total net income and its components followed consecutively by a second statement that should present total other comprehensive income, the components of other comprehensive income, and the total of comprehensive income. The amendments in this update are applicable retrospectively for public entities effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. Early adoption is permitted. The application of this guidance does not have a material impact on the companies' financial position, results of operations and liquidity.

In September 2011, the FASB issued amendments to the guidance for goodwill impairment testing through ASU No. 2011-08, "Intangibles-Goodwill and Other (Topic 350): Testing Goodwill for Impairment." The amendments provide guidance that exempts an entity from calculating the fair value of a reporting unit, if on an initial assessment of qualitative factors it is more likely than not that the fair value of a reporting unit is greater than its carrying amount. For public entities, the amendments are effective for interim and annual goodwill tests performed for years beginning after December 15, 2011. The application of this guidance is not expected to have a material impact on the Companies' financial position, results of operations or liquidity.

In September 2011, the FASB issued amendments to guidance for disclosures related to retirement benefits through ASU No. 2011-09, "Compensation—Retirement Benefits—Multiemployer Plans (Subtopic 715-80): Disclosures about an Employer's Participation in a Multiemployer Plan." The amendment provides guidance that requires employers to provide additional separate disclosures for multiemployer pension plans and multiemployer other postretirement benefit plans about the commitments an employer has made to a multiemployer plan and the potential future cash flow implication of participation in such a plan. For public entities, the amendments are effective for interim and annual periods ending after December 15, 2011. The application of this guidance is not expected to have a material impact on the companies' financial position, results of operations or liquidity.

CECONY [Member]

New Financial Accounting Standards

Note K — New Financial Accounting Standards

In May 2011, the Financial Accounting Standards Board (FASB) issued amendments to the guidance for fair value measurement through Accounting Standards Update (ASU) No. 2011-04, "Fair Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs." The amendments expand Accounting Standards Codification 820's existing disclosure requirements for fair value measurements and makes other amendments. Many of these amendments were made to eliminate unnecessary wording differences between U.S. generally accepted accounting principles and International Financial Reporting Standards. For public entities, the amendments are effective prospectively during interim and annual periods beginning after December 15, 2011. The application of this guidance is not expected to have a material impact on the companies' financial position, results of operations and liquidity.

In June 2011, the FASB issued new guidance for presentation of comprehensive income through ASU No. 2011-05, "Comprehensive Income (Topic 220): Presentation of Comprehensive Income." The amendments require that the comprehensive income be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. In the two-statement approach, the first statement should present total net income and its components followed consecutively by a second statement that should present total other comprehensive income, the components of other comprehensive income, and the total of comprehensive income. The amendments in this update are applicable retrospectively for public entities effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. Early adoption is permitted. The application of this guidance does not have a material impact on the companies' financial position, results of operations and liquidity.

In September 2011, the FASB issued amendments to the guidance for goodwill impairment testing through ASU No. 2011-08, "Intangibles-Goodwill and Other (Topic 350): Testing Goodwill for Impairment." The amendments provide guidance that exempts an entity from calculating the fair value of a reporting unit, if on an initial assessment of qualitative factors it is more likely than not that the fair value of a reporting unit is greater than its carrying amount. For public entities, the amendments are effective for interim and annual goodwill tests performed for years beginning after December 15, 2011. The application of this guidance is not expected to have a material impact on the Companies' financial position, results of operations or liquidity.

In September 2011, the FASB issued amendments to guidance for disclosures related to retirement benefits through ASU No. 2011-09, "Compensation—Retirement Benefits—Multiemployer Plans (Subtopic 715-80): Disclosures about an Employer's Participation in a Multiemployer Plan." The amendment provides guidance that requires employers to provide additional separate disclosures for multiemployer pension plans and multiemployer other postretirement benefit plans about the commitments an employer has made to a multiemployer plan and the potential future cash flow implication of participation in such a plan. For public entities, the amendments are effective for interim and annual periods ending after December 15, 2011. The application of this guidance is not expected to have a material impact on the companies' financial position, results of operations or liquidity.

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Consolidated Income Statement (USD $) In Millions, except Per Share data	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
OPERATING REVENUES
Electric	$ 2,861	$ 2,814	$ 6,883	$ 6,959
Gas	220	229	1,309	1,276
Steam	76	91	508	487
Non-utility	472	573	1,272	1,463
TOTAL OPERATING REVENUES	3,629	3,707	9,972	10,185
OPERATING EXPENSES
Purchased power	1,239	1,425	3,124	3,708
Fuel	73	106	317	342
Gas purchased for resale	73	73	491	482
Other operations and maintenance	783	738	2,213	2,117
Depreciation and amortization	222	211	659	626
Taxes, other than income taxes	483	449	1,387	1,283
TOTAL OPERATING EXPENSES	2,873	3,002	8,191	8,558
OPERATING INCOME	756	705	1,781	1,627
OTHER INCOME (DEDUCTIONS)
Investment and other income		9	19	29
Allowance for equity funds used during construction	2	4	8	13
Other deductions	(3)	(3)	(14)	(12)
TOTAL OTHER INCOME (DEDUCTIONS)	(1)	10	13	30
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	755	715	1,794	1,657
INTEREST EXPENSE
Interest on long-term debt	145	152	437	450
Other interest		7	15	13
Allowance for borrowed funds used during construction	(1)	(2)	(4)	(7)
NET INTEREST EXPENSE	144	157	448	456
INCOME BEFORE INCOME TAX EXPENSE	611	558	1,346	1,201
INCOME TAX EXPENSE	225	205	477	433
NET INCOME	386	353	869	768
Preferred stock dividend requirements of subsidiary	(3)	(3)	(9)	(9)
NET INCOME FOR COMMON STOCK	383	350	860	759
Net income for common stock per common share - basic	$ 1.31	$ 1.24	$ 2.94	$ 2.69
Net income for common stock per common share - diluted	$ 1.30	$ 1.23	$ 2.92	$ 2.68
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK	$ 0.600	$ 0.595	$ 1.800	$ 1.785
AVERAGE NUMBER OF SHARES OUTSTANDING - BASIC (IN MILLIONS)	292.9	283.0	292.5	282.2
AVERAGE NUMBER OF SHARES OUTSTANDING - DILUTED (IN MILLIONS)	294.6	284.6	294.2	283.7
CECONY [Member]
OPERATING REVENUES
Electric	2,644	2,570	6,378	6,402
Gas	197	204	1,156	1,126
Steam	76	91	508	487
TOTAL OPERATING REVENUES	2,917	2,865	8,042	8,015
OPERATING EXPENSES
Purchased power	736	764	1,840	2,102
Fuel	73	105	317	343
Gas purchased for resale	57	63	412	408
Other operations and maintenance	678	637	1,906	1,832
Depreciation and amortization	209	198	618	586
Taxes, other than income taxes	462	432	1,330	1,232
TOTAL OPERATING EXPENSES	2,215	2,199	6,423	6,503
OPERATING INCOME	702	666	1,619	1,512
OTHER INCOME (DEDUCTIONS)
Investment and other income	(6)	5	3	23
Allowance for equity funds used during construction	1	3	6	10
Other deductions	(3)	(2)	(12)	(11)
TOTAL OTHER INCOME (DEDUCTIONS)	(8)	6	(3)	22
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	694	672	1,616	1,534
INTEREST EXPENSE
Interest on long-term debt	130	137	393	406
Other interest	4	5	13	13
Allowance for borrowed funds used during construction	(1)	(1)	(3)	(6)
NET INTEREST EXPENSE	133	141	403	413
INCOME BEFORE INCOME TAX EXPENSE	561	531	1,213	1,121
INCOME TAX EXPENSE	205	196	425	404
NET INCOME	356	335	788	717
Preferred stock dividend requirements of subsidiary	(3)	(3)	(9)	(8)
NET INCOME FOR COMMON STOCK	$ 353	$ 332	$ 779	$ 709

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Environmental Matters (Accrued Liabilities And Regulatory Assets) (Details) (USD $) In Millions	Sep. 30, 2011	Dec. 31, 2010
Site Contingency [Line Items]
Regulatory assets	$ 7,316	$ 7,886
Manufactured Gas Plant Sites [Member]
Site Contingency [Line Items]
Accrued liabilities	432	446
Other Superfund Sites [Member]
Site Contingency [Line Items]
Accrued liabilities	64	66
Superfund Sites [Member]
Site Contingency [Line Items]
Accrued liabilities	496	512
Regulatory assets	$ 681	$ 695

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Fair Value Measurements (Assets And Liabilities Measured At Fair Value On A Recurring Basis) (Details) (USD $) In Millions	12 Months Ended				9 Months Ended																																																																												12 Months Ended				12 Months Ended				12 Months Ended				12 Months Ended
	Dec. 31, 2010		Sep. 30, 2011		Sep. 30, 2011 Derivative Asset [Member]		Sep. 30, 2011 Derivative Asset [Member] Fair Value, Inputs, Level 1 [Member]		Sep. 30, 2011 Derivative Asset [Member] Fair Value, Inputs, Level 2 [Member]		Sep. 30, 2011 Derivative Asset [Member] Fair Value, Inputs, Level 3 [Member]		Sep. 30, 2011 Derivative Asset [Member] Netting Adjustments [Member]		Sep. 30, 2011 Derivative Liability [Member]		Sep. 30, 2011 Derivative Liability [Member] Fair Value, Inputs, Level 1 [Member]		Sep. 30, 2011 Derivative Liability [Member] Fair Value, Inputs, Level 2 [Member]		Sep. 30, 2011 Derivative Liability [Member] Fair Value, Inputs, Level 3 [Member]		Sep. 30, 2011 Derivative Liability [Member] Netting Adjustments [Member]		Sep. 30, 2011 Commodity [Member]	Dec. 31, 2010 Commodity [Member]		Sep. 30, 2011 Commodity [Member] Fair Value, Inputs, Level 1 [Member]	Dec. 31, 2010 Commodity [Member] Fair Value, Inputs, Level 1 [Member]		Sep. 30, 2011 Commodity [Member] Fair Value, Inputs, Level 2 [Member]	Dec. 31, 2010 Commodity [Member] Fair Value, Inputs, Level 2 [Member]		Sep. 30, 2011 Commodity [Member] Fair Value, Inputs, Level 3 [Member]	Dec. 31, 2010 Commodity [Member] Fair Value, Inputs, Level 3 [Member]		Sep. 30, 2011 Commodity [Member] Netting Adjustments [Member]		Dec. 31, 2010 Commodity [Member] Netting Adjustments [Member]		Sep. 30, 2011 Fair Value Interest Rate Contract [Member]		Dec. 31, 2010 Fair Value Interest Rate Contract [Member]		Sep. 30, 2011 Fair Value Interest Rate Contract [Member] Fair Value, Inputs, Level 1 [Member]		Dec. 31, 2010 Fair Value Interest Rate Contract [Member] Fair Value, Inputs, Level 1 [Member]		Sep. 30, 2011 Fair Value Interest Rate Contract [Member] Fair Value, Inputs, Level 2 [Member]		Dec. 31, 2010 Fair Value Interest Rate Contract [Member] Fair Value, Inputs, Level 2 [Member]		Sep. 30, 2011 Fair Value Interest Rate Contract [Member] Fair Value, Inputs, Level 3 [Member]		Dec. 31, 2010 Fair Value Interest Rate Contract [Member] Fair Value, Inputs, Level 3 [Member]		Sep. 30, 2011 Fair Value Interest Rate Contract [Member] Netting Adjustments [Member]		Dec. 31, 2010 Fair Value Interest Rate Contract [Member] Netting Adjustments [Member]		Sep. 30, 2011 Fair Value Other Assets [Member]		Dec. 31, 2010 Fair Value Other Assets [Member]		Sep. 30, 2011 Fair Value Other Assets [Member] Fair Value, Inputs, Level 1 [Member]		Dec. 31, 2010 Fair Value Other Assets [Member] Fair Value, Inputs, Level 1 [Member]		Sep. 30, 2011 Fair Value Other Assets [Member] Fair Value, Inputs, Level 2 [Member]		Dec. 31, 2010 Fair Value Other Assets [Member] Fair Value, Inputs, Level 2 [Member]		Sep. 30, 2011 Fair Value Other Assets [Member] Fair Value, Inputs, Level 3 [Member]		Dec. 31, 2010 Fair Value Other Assets [Member] Fair Value, Inputs, Level 3 [Member]		Sep. 30, 2011 Fair Value Other Assets [Member] Netting Adjustments [Member]		Dec. 31, 2010 Fair Value Other Assets [Member] Netting Adjustments [Member]		Dec. 31, 2010 Fair Value, Inputs, Level 1 [Member]		Sep. 30, 2011 Fair Value, Inputs, Level 1 [Member]		Dec. 31, 2010 Fair Value, Inputs, Level 2 [Member]		Sep. 30, 2011 Fair Value, Inputs, Level 2 [Member]		Dec. 31, 2010 Fair Value, Inputs, Level 3 [Member]		Sep. 30, 2011 Fair Value, Inputs, Level 3 [Member]		Dec. 31, 2010 Netting Adjustments [Member]		Sep. 30, 2011 Netting Adjustments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets			$ 79	[1]																					$ 79	$ 106	[1]	$ 2	$ 2	[1]	$ 52	$ 72	[1]	$ 69	$ 144	[1]	$ (44)	[2]	$ (112)	[1],[2]																					$ 175	[3]	$ 166	[3]	$ 75	[3]	$ 65	[3]		[3]		[3]	$ 100	[3]	$ 101	[3]		[2],[3]		[2],[3]			$ 3	[1]			$ 51	[1]			$ 69	[1]			$ (44)	[1],[2]
Total assets	272		254																																																																														67		78		72		51		245		169		(112)	[2]	(44)	[2]
Transfer in	(45)	[4],[5],[6]			1	[4],[7]	1	[4],[7]		[4],[7]		[4],[7]		[2],[4],[7]	24	[4],[8]		[4],[8]	23	[4],[8]	1	[4],[8]		[2],[4],[8]																																																										[4],[5],[6]			(36)	[4],[5],[6]			(9)	[4],[5],[6]				[2],[4],[5],[6]
Transfer out	45	[4],[5],[6]			(1)	[4],[7]		[4],[7]	(1)	[4],[7]		[4],[7]		[2],[4],[7]	(24)	[4],[8]		[4],[8]	(1)	[4],[8]	(23)	[4],[8]		[2],[4],[8]																																																										[4],[5],[6]			9	[4],[5],[6]			36	[4],[5],[6]				[2],[4],[5],[6]
Derivative liabilities	191	[1]	121	[1]																					121	191		10	4		130	270		98	205		(117)	[2]	(288)	[2]	9	[9]	10	[9]		[9]		[9]		[9]		[9]	9	[9]	10	[9]		[2],[9]		[2],[9]																					4	[1]	10	[1]	243	[1]	152	[1]	232	[1]	76	[1]	(288)	[1],[2]	(117)	[1],[2]
Total liabilities	$ 201		$ 130																																																																														$ 4		$ 10		$ 243		$ 152		$ 242		$ 85		$ (288)	[2]	$ (117)	[2]

[1] A significant portion of the commodity derivative contracts categorized in Level 3 is valued using either an industry acceptable model or an internally developed model with observable inputs. The models also include some less readily observable inputs resulting in the classification of the entire contract as Level 3. See Note I.

[2] 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.

[3] Other assets are comprised of assets such as life insurance contracts within the Deferred Income Plan and Supplemental Retirement Income Plans, held in rabbi trusts.

[4] The Companies' policy is to recognize transfers into and transfers out of the levels at the end of the reporting period.

[5] Transferred from Level 2 to Level 3 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

[6] Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2009 to less than one year as of December 31, 2010.

[7] Transferred from Level 2 to Level 1 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall.

[8] Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 2010 to less than one year as of September 30, 2011.

[9] See Note I.

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Derivative Instruments And Hedging Activities (Changes In The Fair Values Of Commodity Derivatives) (Details) (USD $) In Millions	3 Months Ended				9 Months Ended
	Sep. 30, 2011		Sep. 30, 2010		Sep. 30, 2011		Sep. 30, 2010
Derivatives, Fair Value [Line Items]
Total deferred gains	$ (1)	[1]			$ 3	[1]
Total deferred losses	(53)	[1]			(59)	[1]
Net deferred losses	(54)	[1]	(130)	[1]	(56)	[1]	(359)	[1]
Pre-tax gain/(loss) recognized in income	40	[1]	(23)	[1]	120	[1]	(118)	[1]
Unrealized gain/(loss) on derivatives, tax					(9)
Derivative Asset [Member]
Derivatives, Fair Value [Line Items]
Total deferred losses			(127)	[1]			(351)	[1]
Derivative Liability [Member]
Derivatives, Fair Value [Line Items]
Total deferred losses			(3)	[1]			(8)	[1]
Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Current-Deferred derivative gains			(3)	[1]			(8)	[1]
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Deferred gain/(loss), asset			(61)	[1]			(127)	[1]
Deferred Derivative Gains [Member]
Derivatives, Fair Value [Line Items]
Current-Deferred derivative gains	(2)	[1]
Regulatory Liabilities, Long Term [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains	1	[1]			3	[1]
Deferred Derivative Losses [Member]
Derivatives, Fair Value [Line Items]
Deferred derivative losses, current	12	[1]			80	[1]
Recoverable Energy Costs [Member]
Derivatives, Fair Value [Line Items]
Deferred gain/(loss), asset	(75)	[1]	(70)	[1]	(177)	[1]	(205)	[1]
Regulatory Assets, Long Term [Member]
Derivatives, Fair Value [Line Items]
Deferred gain/(loss), asset	10	[1]	4	[1]	38	[1]	(19)	[1]
Purchased Power Expense [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income	29	[1],[2]	(26)	[1],[3]	81	[1],[4]	(132)	[1],[5]
Unrealized gain/(loss) on derivatives, tax	(1)		(34)		59		(34)
Gas Purchased For Resale [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income	6	[1]	(1)	[1]	17	[1]	(7)	[1]
Non-Utility Revenue [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income	5	[1],[2]	4	[1],[3]	22	[1],[4]	21	[1],[5]
Unrealized gain/(loss) on derivatives, tax	$ (10)		$ (3)		$ (35)		$ (1)

[1] Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

[2] For the three months ended September 30, 2011 Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss) of $(10) million and $(1) million, respectively.

[3] For the three months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(3)million and $(34) million, respectively.

[4] For the nine months ended September 30, 2011, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax (loss)/gain of $(35) million and $59 million, respectively.

[5] For the nine months ended September 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(1) million and $(34) million, respectively.

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Derivative Instruments And Hedging Activities (Number Of Derivative Contracts By Commodity Type) (Details)	9 Months Ended
	Sep. 30, 2011
Derivatives, Fair Value [Line Items]
Number of Energy Contracts	1,565	[1]
Description Of Derivative Activity Volume Electric Derivatives [Member]
Derivatives, Fair Value [Line Items]
Number of Energy Contracts	810	[1]
MWhs	16,479,730	[2]
Number of Capacity Contracts	73	[1]
MWs	8,201	[2],[3]
Description Of Derivative Activity Volume Gas Derivatives [Member]
Derivatives, Fair Value [Line Items]
Number of Energy Contracts	682	[1]
Dths	98,382,500	[2],[3]

[1] Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.

[2] Volumes are reported net of long and short positions.

[3] Volumes are reported net of long and short positions

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Environmental Matters (Environmental Remediation Costs) (Details) (USD $) In Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2011	Sep. 30, 2010	Sep. 30, 2011	Sep. 30, 2010
Environmental Matters [Abstract]
Remediation costs incurred	$ 9	$ 9	$ 24	$ 32