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 MARCH 31, 2012

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 April 27, 2012, Con Edison had outstanding 292,904,261 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
NYISO	New York Independent System Operator
NYPA	New York Power Authority
NYSAG	New York State Attorney General
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
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	Kilovolt
kWh	Kilowatt-hour
mdths	Thousand dekatherms
MMlbs	Million pounds
MVA	Megavolt ampere
MW	Megawatt 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, 2012
Form 10-K	The Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2011
LTIP	Long Term Incentive Plan
Moody’s	Moody’s Investors Service
S&P	Standard & Poor’s Financial Services LLC
VaR	Value-at-Risk

3

TABLE OF CONTENTS

		PAGE
PART I—Financial Information
ITEM  1	Financial Statements (Unaudited)
	Con Edison
	Consolidated Income Statement		6
	Consolidated Statement of Comprehensive Income		7
	Consolidated Statement of Cash Flows		8
	Consolidated Balance Sheet		9
	Consolidated Statement of Common Shareholders’ Equity		11
	CECONY
	Consolidated Income Statement		12
	Consolidated Statement of Comprehensive Income		13
	Consolidated Statement of Cash Flows		14
	Consolidated Balance Sheet		15
	Consolidated Statement of Common Shareholder’s Equity		17
	Notes to Financial Statements (Unaudited)		18
ITEM  2	Management’s Discussion and Analysis of Financial Condition and Results of Operations		35
ITEM  3	Quantitative and Qualitative Disclosures About Market Risk		50
ITEM  4	Controls and Procedures		50
PART II—Other Information
ITEM  1	Legal Proceedings		51
ITEM 1A	Risk Factors		51
ITEM  2	Unregistered Sales of Equity Securities and Use of Proceeds		51
ITEM  6	Exhibits		52
	Signatures		52

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 March 31,
	2012			2011
	(Millions of Dollars/ Except Share Data)
OPERATING REVENUES
Electric	$	1,862		$	1,869
Gas		645			755
Steam		263			325
Non-utility		308			400
TOTAL OPERATING REVENUES		3,078			3,349
OPERATING EXPENSES
Purchased power		781			865
Fuel		108			176
Gas purchased for resale		196			308
Operations and maintenance		749			698
Depreciation and amortization		233			218
Taxes, other than income taxes		450			458
TOTAL OPERATING EXPENSES		2,517			2,723
OPERATING INCOME		561			626
OTHER INCOME (DEDUCTIONS)
Investment and other income		7			9
Allowance for equity funds used during construction		—			4
Other deductions		(4	)		(4	)
TOTAL OTHER INCOME (DEDUCTIONS)		3			9
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE		564			635
INTEREST EXPENSE
Interest on long-term debt		145			147
Other interest		5			7
Allowance for borrowed funds used during construction		—			(2	)
NET INTEREST EXPENSE		150			152
INCOME BEFORE INCOME TAX EXPENSE		414			483
INCOME TAX EXPENSE		134			169
NET INCOME		280			314
Preferred stock dividend requirements of subsidiary		(3	)		(3	)
NET INCOME FOR COMMON STOCK	$	277		$	311
Net income for common stock per common share – basic	$	0.95		$	1.07
Net income for common stock per common share – diluted	$	0.94		$	1.06
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK	$	0.605		$	0.600
AVERAGE NUMBER OF SHARES OUTSTANDING – BASIC (IN MILLIONS)		292.9			292.0
AVERAGE NUMBER OF SHARES OUTSTANDING – DILUTED (IN MILLIONS)		294.5			293.6

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

6

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2012			2011
	(Millions of Dollars)
NET INCOME	$	280		$	314
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension plan liability adjustments, net of $5 and $2 taxes in 2012 and 2011, respectively		7			3
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES		7			3
COMPREHENSIVE INCOME	$	287		$	317
Preferred stock dividend requirements of subsidiary		(3	)		(3	)
COMPREHENSIVE INCOME FOR COMMON STOCK	$	284		$	314

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

7

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2012			2011
	(Millions of Dollars)
OPERATING ACTIVITIES
Net Income	$	280		$	314
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization		233			218
Deferred income taxes		68			232
Rate case amortization and accruals		31			19
Common equity component of allowance for funds used during construction		—			(4	)
Net derivative losses/(gains)		31			(37	)
Other non-cash items (net)		64			(17	)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers, less allowance for uncollectibles		54			(5	)
Materials and supplies, including fuel oil and gas in storage		31			103
Other receivables and other current assets		(2	)		66
Prepayments		(286	)		(217	)
Accounts payable		(78	)		(154	)
Pensions and retiree benefits obligations		253			259
Pensions and retiree benefits contribution		(184	)		(491	)
Accrued taxes		41			(20	)
Accrued interest		52			51
Deferred charges, noncurrent assets and other regulatory assets		(255	)		(19	)
Deferred credits and other regulatory liabilities		117			67
Other assets		—			(1	)
Other liabilities		(48	)		(2	)
NET CASH FLOWS FROM OPERATING ACTIVITIES		402			362
INVESTING ACTIVITIES
Utility construction expenditures		(471	)		(394	)
Cost of removal less salvage		(43	)		(39	)
Non-utility construction expenditures		(9	)		(23	)
Proceeds from investment tax credits and grants related to renewable energy investments		6			—
Net investment in Pilesgrove solar project and other		27			—
Loan to affiliate		—			(40	)
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(490	)		(496	)
FINANCING ACTIVITIES
Net proceeds from short-term debt		—			464
Retirement of long-term debt		(1	)		(1	)
Issuance of long-term debt		400			—
Issuance of common shares for stock plans, net of repurchases		(8	)		25
Debt issuance costs		(4	)		—
Common stock dividends		(175	)		(173	)
Preferred stock dividends		(3	)		(3	)
NET CASH FLOWS FROM FINANCING ACTIVITIES		209			312
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD		121			178
BALANCE AT BEGINNING OF PERIOD		648			338
BALANCE AT END OF PERIOD	$	769		$	516
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash paid/(refunded) during the period for:
Interest	$	89		$	90
Income taxes	$	—		$	(172	)

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

8

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	March 31, 2012		December 31, 2011
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$	769	$	648
Accounts receivable – customers, less allowance for uncollectible accounts of $87 in 2012 and 2011		1,069		1,123
Accrued unbilled revenue		379		474
Other receivables, less allowance for uncollectible accounts of $10 in 2012 and 2011		249		303
Fuel oil, gas in storage, materials and supplies, at average cost		325		356
Prepayments		431		145
Deferred tax assets – current		285		266
Regulatory assets		192		164
Other current assets		205		159
TOTAL CURRENT ASSETS		3,904		3,638
INVESTMENTS		440		455
UTILITY PLANT, AT ORIGINAL COST
Electric		21,520		21,105
Gas		4,821		4,727
Steam		2,015		1,983
General		2,093		1,960
TOTAL		30,449		29,775
Less: Accumulated depreciation		6,153		6,051
Net		24,296		23,724
Construction work in progress		920		1,241
NET UTILITY PLANT		25,216		24,965
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $61 and $59 in 2012 and 2011, respectively		98		89
Construction work in progress		39		39
NET PLANT		25,353		25,093
OTHER NONCURRENT ASSETS
Goodwill		429		429
Intangible assets, less accumulated amortization of $3 in 2012 and 2011		3		3
Regulatory assets		9,276		9,337
Other deferred charges and noncurrent assets		296		259
TOTAL OTHER NONCURRENT ASSETS		10,004		10,028
TOTAL ASSETS	$	39,701	$	39,214

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

9

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	March 31, 2012		December 31, 2011
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$	1,030	$	530
Accounts payable		844		955
Customer deposits		306		303
Accrued taxes		229		188
Accrued interest		212		160
Accrued wages		91		91
Fair value of derivative liabilities		198		169
Regulatory liabilities		286		118
Preferred stock redemption		239		—
Other current liabilities		405		473
TOTAL CURRENT LIABILITIES		3,840		2,987
NONCURRENT LIABILITIES
Obligations under capital leases		2		2
Provision for injuries and damages		158		181
Pensions and retiree benefits		4,605		4,835
Superfund and other environmental costs		537		489
Asset retirement obligations		147		145
Fair value of derivative liabilities		54		48
Other noncurrent liabilities		131		131
TOTAL NONCURRENT LIABILITIES		5,634		5,831
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits		7,712		7,563
Regulatory liabilities		846		977
Other deferred credits		83		64
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES		8,641		8,604
LONG-TERM DEBT		10,041		10,143
SHAREHOLDERS’ EQUITY
Common shareholders’ equity (See Statement of Common Shareholders’ Equity)		11,545		11,436
Preferred stock of subsidiary		—		213
TOTAL SHAREHOLDERS’ EQUITY		11,545		11,649
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	39,701	$	39,214

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, 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
BALANCE AS OF DECEMBER 31, 2011		292,888,521		$	32	$	4,991	$	7,568			23,194,075	$	(1,033	)	$	(64	)	$	(58	)	$	11,436
Net income for common stock									277														277
Common stock dividends									(177	)													(177	)
Issuance of common shares for stock plans, net of repurchases		(7,225	)									7,225		(2	)								(2	)
Preferred stock redemption																	4						4
Other comprehensive income																				7			7
BALANCE AS OF MARCH 31, 2012		292,881,296		$	32	$	4,991	$	7,668			23,201,300	$	(1,035	)	$	(60	)	$	(51	)	$	11,545

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 Month Ended March 31,
	2012			2011
	(Millions of Dollars)
OPERATING REVENUES
Electric	$	1,735		$	1,721
Gas		563			663
Steam		263			325
TOTAL OPERATING REVENUES		2,561			2,709
OPERATING EXPENSES
Purchased power		447			483
Fuel		108			176
Gas purchased for resale		169			263
Operations and maintenance		645			597
Depreciation and amortization		218			204
Taxes, other than income taxes		430			440
TOTAL OPERATING EXPENSES		2,017			2,163
OPERATING INCOME		544			546
OTHER INCOME (DEDUCTIONS)
Investment and other income		5			5
Allowance for equity funds used during construction		—			3
Other deductions		(3	)		(3	)
TOTAL OTHER INCOME (DEDUCTIONS)		2			5
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE		546			551
INTEREST EXPENSE
Interest on long-term debt		131			132
Other interest		5			5
Allowance for borrowed funds used during construction		—			(2	)
NET INTEREST EXPENSE		136			135
INCOME BEFORE INCOME TAX EXPENSE		410			416
INCOME TAX EXPENSE		134			145
NET INCOME		276			271
Preferred stock dividend requirements		(3	)		(3	)
NET INCOME FOR COMMON STOCK	$	273		$	268

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

12

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Month Ended March 31,
	2012		2011
	(Millions of Dollars)
NET INCOME	$	276	$	271
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension plan liability adjustments, net of $— taxes in 2012 and 2011		—		—
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES		—		—
COMPREHENSIVE INCOME	$	276	$	271

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

13

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2012			2011
	(Millions of Dollars)
OPERATING ACTIVITIES
Net income	$	276		$	271
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization		218			204
Deferred income taxes		66			207
Rate case amortization and accruals		31			19
Common equity component of allowance for funds used during construction		—			(3	)
Other non-cash items (net)		15			10
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers, less allowance for uncollectibles		43			22
Materials and supplies, including fuel oil and gas in storage		22			84
Other receivables and other current assets		16			(77	)
Prepayments		(287	)		(291	)
Accounts payable		(48	)		(119	)
Pensions and retiree benefits obligations		209			236
Pensions and retiree benefits contribution		(184	)		(491	)
Accrued taxes		57			(37	)
Accrued interest		42			44
Superfund and environmental remediation costs (net)		(1	)		—
Deferred charges, noncurrent assets and other regulatory assets		(179	)		(63	)
Deferred credits and other regulatory liabilities		108			52
Other liabilities		(36	)		4
NET CASH FLOWS FROM OPERATING ACTIVITIES		368			72
INVESTING ACTIVITIES
Utility construction expenditures		(446	)		(376	)
Cost of removal less salvage		(41	)		(37	)
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(487	)		(413	)
FINANCING ACTIVITIES
Net proceeds from short-term debt		—			464
Issuance of long-term debt		400			—
Debt issuance costs		(4	)		—
Dividend to parent		(171	)		(170	)
Preferred stock dividends		(3	)		(3	)
NET CASH FLOWS USED IN FINANCING ACTIVITIES		222			291
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD		103			(50	)
BALANCE AT BEGINNING OF PERIOD		372			78
BALANCE AT END OF PERIOD	$	475		$	28
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash paid/(refunded) during the period for:
Interest	$	83		$	82
Income taxes	$	(20	)	$	35

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

14

Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	March 31, 2012		December 31, 2011
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$	475	$	372
Accounts receivable – customers, less allowance for uncollectible accounts of $79 in 2012 and 2011		934		977
Other receivables, less allowance for uncollectible accounts of $9 in 2012 and 2011		110		102
Accrued unbilled revenue		285		366
Accounts receivable from affiliated companies		36		54
Fuel oil, gas in storage, materials and supplies, at average cost		286		308
Prepayments		372		85
Regulatory assets		159		140
Deferred tax assets – current		170		157
Other current assets		97		100
TOTAL CURRENT ASSETS		2,924		2,661
INVESTMENTS		188		177
UTILITY PLANT AT ORIGINAL COST
Electric		20,284		19,886
Gas		4,285		4,200
Steam		2,015		1,983
General		1,917		1,785
TOTAL		28,501		27,854
Less: Accumulated depreciation		5,616		5,523
Net		22,885		22,331
Construction work in progress		853		1,165
NET UTILITY PLANT		23,738		23,496
NON-UTILITY PROPERTY
Non-utility property, less accumulated depreciation of $24 in 2012 and 2011		6		6
NET PLANT		23,744		23,502
OTHER NONCURRENT ASSETS
Regulatory assets		8,645		8,661
Other deferred charges and noncurrent assets		254		217
TOTAL OTHER NONCURRENT ASSETS		8,899		8,878
TOTAL ASSETS	$	35,755	$	35,218

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

15

Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	March 31, 2012		December 31, 2011
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$	1,024	$	525
Accounts payable		690		774
Accounts payable to affiliated companies		17		16
Customer deposits		293		290
Accrued taxes		17		32
Accrued taxes to affiliated companies		198		126
Accrued interest		175		133
Accrued wages		82		81
Fair value of derivative liabilities		112		98
Regulatory liabilities		242		79
Preferred stock redemption		239		—
Other current liabilities		338		396
TOTAL CURRENT LIABILITIES		3,427		2,550
NONCURRENT LIABILITIES
Obligations under capital leases		2		2
Provision for injuries and damages		151		173
Pensions and retiree benefits		4,142		4,337
Superfund and other environmental costs		421		373
Asset retirement obligations		147		145
Fair value of derivative liabilities		31		24
Other noncurrent liabilities		121		120
TOTAL NONCURRENT LIABILITIES		5,015		5,174
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits		7,059		6,921
Regulatory liabilities		730		861
Other deferred credits		81		61
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES		7,870		7,843
LONG-TERM DEBT		9,119		9,220
SHAREHOLDER’S EQUITY
Common shareholder’s equity (See Statement of Common Shareholder’s Equity)		10,324		10,218
Preferred stock		—		213
TOTAL SHAREHOLDER’S EQUITY		10,324		10,431
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$	35,755	$	35,218

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

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF 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, 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	)
Other comprehensive income																	—			—
BALANCE AS OF MARCH 31, 2011		235,488,094	$	589	$	4,234	$	6,230		$	(962	)	$	(64	)	$	(6	)	$	10,021
BALANCE AS OF DECEMBER 31, 2011		235,488,094	$	589	$	4,234	$	6,429		$	(962	)	$	(64	)	$	(8	)	$	10,218
Net income								276												276
Common stock dividend to parent								(171	)											(171	)
Cumulative preferred dividends								(3	)											(3	)
Preferred stock redemption														4						4
Other comprehensive income																	—			—
BALANCE AS OF MARCH 31, 2012		235,488,094	$	589	$	4,234	$	6,531		$	(962	)	$	(60	)	$	(8	)	$	10,324

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, 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 months ended March 31, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011
Net income for common stock	$	277	$	311
Weighted average common shares outstanding – Basic		292.9		292.0
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		293.6
Net income for common stock per common share – basic	$	0.95	$	1.07
Net income for common stock per common share – diluted	$	0.94	$	1.06

Note B — Regulatory Matters

Rate Agreements

CECONY — Electric

In March 2012, the NYSPSC issued an order requiring that the $134 million surcharge that was to have been collected from customers during the rate year ending March 2013 instead be offset using certain CECONY regulatory liabilities that would have otherwise been refundable to or applied for the benefit of customers after the rate year.

O&R — Electric

On February 24, 2012, O&R, the staff of the NYSPSC and the Utility Intervention Unit of New York State’s Division of Consumer Protection entered into a Joint Proposal with respect to the Company’s rates for electric delivery service rendered in New York. The Joint Proposal, which is subject to NYSPSC approval, covers the three-year period from July 2012 through June 2015. The Joint Proposal provides for electric base rate increases of $19.4 million, $8.8 million and $15.2 million, effective July 2012, 2013 and 2014, respectively, which can be implemented, at the NYSPSC’s option, with increases of $15.2 million effective July 2012 and 2013 and an increase of $13.1 million, together with a surcharge of $2.1 million, effective July 2014. The Joint Proposal reflects the following major items:

• a weighted average cost of capital of 7.61 percent, 7.65 percent and 7.48 percent for the rate years ending June 30, 2013, 2014 and 2015, respectively, reflecting:

• a return on common equity of 9.4 percent, 9.5 percent and 9.6 percent for the rate years ending June 30, 2013, 2014 and 2015, respectively;

• cost of long-term debt of 6.07 percent for each of the rate years ending June 30, 2013 and 2014 and 5.64 percent for the rate year ending June 30 2015;

• common equity ratio of 48 percent for each of the rate years ending June 30, 2013, 2014 and 2015; and

• average rate base of $671 million, $708 million and $759 million for the rate years ending June 30, 2013, 2014 and 2015, respectively;

• sharing with electric customers of any actual earnings, excluding the effects of any penalties and certain other items, above specified percentage returns on common equity (based on the actual average common equity ratio, subject to a 50 percent maximum):

• the company will allocate to customers the revenue requirement equivalent of 50 percent, 75 percent and 90 percent of any such earnings for each rate year in excess of 80 basis points, 180 basis points and 280 basis points, respectively, above the return on common equity for that rate year indicated above; and

• the earnings sharing allocation between the company and customers will be done on a cumulative basis at the end of rate year three;

• continuation of a revenue decoupling mechanism;

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• continuation of a provision which defers as a regulatory liability for the benefit of customers or, subject to certain limitations, a regulatory asset for recovery from customers, as the case may be, the revenue requirement impact of the amount by which actual average net utility plant for each rate year is different than the average net utility plant reflected in rates ($678 million, $704 million and $753 million for the rate years ending June 30, 2013, 2014 and 2015, respectively);

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

• 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;

• provisions under which property taxes are reconciled to amounts reflected in rates; and

• 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.

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 H). 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 March 31, 2012, the company had collected an estimated $887 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 March 31, 2012, the company had an $8 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 G.

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Regulatory Assets and Liabilities

Regulatory assets and liabilities at March 31, 2012 and December 31, 2011 were comprised of the following items:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Regulatory assets
Unrecognized pension and other postretirement costs	$	5,594	$	5,852	$	5,337	$	5,554
Future income tax		1,840		1,798		1,764		1,724
Environmental remediation costs		729		681		613		564
Pension and other post retirement benefits deferrals		219		198		185		157
Revenue taxes		167		163		161		158
Surcharge for New York State assessment		143		90		133		82
Deferred storm costs		125		128		79		80
Net electric deferrals		116		121		116		121
Deferred derivative losses – long-term		78		60		61		44
O&R transition bond charges		43		44		—		—
Preferred stock redemption		30		—		30		—
Workers’ compensation		22		23		21		23
Property tax reconciliation		13		13		—		—
Recoverable energy costs – long-term		—		14		—		14
Other		157		152		145		140
Regulatory assets – long-term		9,276		9,337		8,645		8,661
Deferred derivative losses – current		192		164		159		140
Regulatory assets – current		192		164		159		140
Total Regulatory Assets	$	9,468	$	9,501	$	8,804	$	8,801
Regulatory liabilities
Allowance for cost of removal less salvage	$	457	$	448	$	379	$	372
Property tax reconciliation		68		35		68		35
World Trade Center settlement proceeds		62		62		62		62
Net unbilled revenue deferrals		51		104		51		104
Long-term interest rate reconciliation		42		30		42		30
Carrying charges on transmission and distribution net plant		41		38		18		14
Gas line losses		17		21		17		21
Expenditure prudence proceeding		8		11		8		11
Energy efficiency programs		6		22		6		20
Other		94		206		79		192
Regulatory liabilities – long-term		846		977		730		861
Electric surcharge offset		134		—		134		—
Refundable energy costs – current		99		51		55		12
Revenue decoupling mechanism		51		66		51		66
Deferred derivative gains – current		2		1		2		1
Regulatory liabilities – current		286		118		242		79
Total Regulatory Liabilities	$	1,132	$	1,095	$	972	$	940

Note C — Capitalization

In March 2012, CECONY issued $400 million of 4.20 percent 30-year debentures, $239 million of the net proceeds from the sale of which were used to redeem on May 1, 2012 all outstanding shares of its $5 Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value).

The carrying amounts and fair values of long-term debt are:

(millions of dollars)	March 31, 2012				December 31, 2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison	$	11,071	$	12,892	$	10,673	$	12,744
CECONY	$	10,143	$	11,757	$	9,745	$	11,593

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Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,256 million and $636 million of the fair value of long-term debt at March 31, 2012 are classified as Level 2 and Level 3, respectively. For CECONY, $11,121 million and $636 million of the fair value of long-term debt at March 31, 2012 are classified as Level 2 and Level 3, respectively (see Note K).

Note D — Short-Term Borrowing

At March 31, 2012, Con Edison and CECONY had no commercial paper outstanding. The Companies have not borrowed under their October 2011 credit agreement. Con Edison had $183 million of letters of credit outstanding under the credit agreement (including $168 million for CECONY).

Note E — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic benefit costs for the three months ended March 31, 2012 and 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses	$	59		$	47		$	55		$	44
Interest cost on projected benefit obligation		137			140			128			131
Expected return on plan assets		(176	)		(183	)		(168	)		(175	)
Amortization of net actuarial loss		177			132			168			125
Amortization of prior service costs		2			2			2			2
NET PERIODIC BENEFIT COST	$	199		$	138		$	185		$	127
Cost capitalized		(64	)		(48	)		(63	)		(45	)
Cost deferred		(37	)		(51	)		(38	)		(52	)
Cost charged to operating expenses	$	98		$	39		$	84		$	30

Expected Contributions

Based on estimates as of March 31, 2012, the Companies expect to make contributions to the pension plan during 2012 of $775 million (of which $721 million is to be contributed by CECONY). During the first quarter of 2012, CECONY contributed $184 million to the pension plan. The Companies expect to fund $12 million for the non-qualified supplemental plans in 2012. The Companies’ policy is to fund their accounting cost to the extent tax deductible.

Note F — Other Postretirement Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic postretirement benefit costs for the three months ended March 31, 2012 and 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost	$	7		$	6		$	5		$	5
Interest cost on accumulated other postretirement benefit obligation		18			21			16			18
Expected return on plan assets		(21	)		(22	)		(18	)		(19	)
Amortization of net actuarial loss		25			22			22			20
Amortization of prior service cost		(5	)		(2	)		(4	)		(3	)
Amortization of transition obligation		—			1			—			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	24		$	26		$	21		$	22
Cost capitalized		(8	)		(9	)		(7	)		(8	)
Cost charged		7			4			4			3
Cost charged to operating expenses	$	23		$	21		$	18		$	17

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Expected Contributions

Based on estimates as of March 31, 2012, Con Edison expects to make a contribution of $87 million, including $74 million for CECONY, to the other postretirement benefit plans in 2012.

Note G — Environmental Matters

Superfund Sites

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

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

For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of 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 March 31, 2012 and December 31, 2011 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued Liabilities:
Manufactured gas plant sites	$	466	$	422	$	351	$	307
Other Superfund Sites		71		67		70		66
Total	$	537	$	489	$	421	$	373
Regulatory assets	$	729	$	681	$	613	$	564

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 and insurance recoveries received related to Superfund Sites for the three months ended March 31, 2012 and 2011, were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred	$	7	$	6	$	7	$	5
Insurance recoveries received		—		—		—		—

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

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$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 March 31, 2012 and December 31, 2011 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued liability – asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets – asbestos suits	$	10	$	10	$	10	$	10
Accrued liability – workers’ compensation	$	96	$	98	$	92	$	93
Regulatory assets – workers’ compensation	$	22	$	23	$	21	$	23

Note H — Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately 93 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

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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 been convicted of 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 2011 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 $(65) million at March 31, 2012 and $(55) million at December 31, 2011 and is comprised of a $228 million gross investment less $293 million of deferred tax liabilities at March 31, 2012 and $234 million gross investment less $289 million of deferred tax liabilities at December 31, 2011.

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 appealed the decision in December 2011.

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

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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 March 31, 2012, in the aggregate, was $240 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 $114 million net of tax at March 31, 2012.

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 $760 million at March 31, 2012 and December 31, 2011, respectively.

A summary, by type and term, of Con Edison’s total guarantees at March 31, 2012 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	637	$	4	$	66	$	707
Intra-company guarantees		15		—		1		16
Other guarantees		33		4		—		37
TOTAL	$	685	$	8	$	67	$	760

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 and Con Edison Development also guarantee the following:

• $7 million relates to guarantees issued by Con Edison to CECONY covering a former Con Edison subsidiary’s lease payment 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;

• $5 million for guarantees provided by Con Edison Development to Travelers Insurance Company for indemnity agreements for surety bonds in connection with the construction and operation of solar facilities performed by its subsidiaries; 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 March 31, 2012.

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Note I — Financial Information by Business Segment

The financial data for the business segments are as follows:

	For the Three Months Ended March 31,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012			2011			2012			2011			2012		2011		2012			2011
CECONY
Electric	$	1,735		$	1,721		$	3		$	3		$	173	$	161	$	224		$	217
Gas		563			663			1			1			29		27		221			204
Steam		263			325			19			20			16		16		99			125
Consolidation adjustments		—			—			(23	)		(24	)		—		—		—			—
Total CECONY	$	2,561		$	2,709		$	—		$	—		$	218	$	204	$	544		$	546
O&R
Electric	$	128		$	149		$	—		$	—		$	9	$	9	$	8		$	10
Gas		82			92			—			—			4		3		30			28
Total O&R	$	210		$	241		$	—		$	—		$	13	$	12	$	38		$	38
Competitive energy businesses	$	310		$	408		$	2		$	3		$	2	$	2	$	(20	)	$	44
Other*		(3	)		(9	)		(2	)		(3	)		—		—		(1	)		(2	)
Total Con Edison	$	3,078		$	3,349		$	—		$	—		$	233	$	218	$	561		$	626

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

Note J — 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 the Companies’ commodity derivatives at March 31, 2012 and December 31, 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Fair value of net derivative assets/(liabilities) – gross	$	(331	)	$	(249	)	$	(181	)	$	(144	)
Impact of netting of cash collateral		156			110			64			46
Fair value of net derivative assets/(liabilities) – net	$	(175	)	$	(139	)	$	(117	)	$	(98	)

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 March 31, 2012, Con Edison and CECONY had $121 million and $12 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $46 million with investment-grade counterparties, $37 million with commodity exchange brokers, $36 million with independent system operators and $2 million with non-rated counterparties. CECONY’s 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.

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The fair values of the Companies’ commodity derivatives at March 31, 2012 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivatives Asset
Current	Other current assets	$	179		$	20
Long-term	Other deferred charges and non-current assets		25			6
Total derivatives asset		$	204		$	26
Impact of netting			(134	)		—
Net derivatives asset		$	70		$	26
Derivatives Liability
Current	Fair value of derivative liabilities	$	433		$	149
Long-term	Fair value of derivative liabilities		102			58
Total derivatives liability		$	535		$	207
Impact of netting			(290	)		(64	)
Net derivatives liability		$	245		$	143

(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, 2011 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivatives Asset
Current	Other current assets	$	139		$	16
Long-term	Other deferred charges and non-current assets		26			14
Total derivatives asset		$	165		$	30
Impact of netting			(95	)		(6	)
Net derivatives asset		$	70		$	24
Derivatives Liability
Current	Fair value of derivative liabilities	$	331		$	127
Long-term	Fair value of derivative liabilities		83			48
Total derivatives liability		$	414		$	175
Impact of netting			(205	)		(53	)
Net derivatives liability		$	209		$	122

(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.

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The following table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three months ended March 31, 2012:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended March 31, 2012
(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	$	1		$	1
Total deferred gains		$	1		$	1
Current	Deferred derivative losses	$	(28	)	$	(19	)
Current	Recoverable energy costs		(74	)		(56	)
Long-term	Regulatory assets		(18	)		(17	)
Total deferred losses		$	(120	)	$	(92	)
Net deferred losses		$	(119	)	$	(91	)
	Income Statement Location
Pre-tax loss recognized in income
	Purchased power expense	$	(86	)(b)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		(3	)(b)		—
Total pre-tax loss recognized in income		$	(90	)	$	—

(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 March 31, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax loss of $(4) million and $(27) million, respectively.

The following table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three months ended March 31, 2011:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended March 31, 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	$	6		$	5
Long-term	Regulatory liabilities		3			3
Total deferred gains		$	9		$	8
Current	Deferred derivative losses	$	44		$	35
Current	Recoverable energy costs		(49	)		(42	)
Long-term	Regulatory assets		17			11
Total deferred losses		$	12		$	4
Net deferred losses		$	21		$	12
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(21	)(b)	$	—
	Gas purchased for resale		(6	)		—
	Non-utility revenue		10	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(17	)	$	—

(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 March 31, 2011, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $50 million, respectively.

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As of March 31, 2012, Con Edison had 1,392 contracts, including 582 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		754		16,197,114		59		7,639		579		91,840,940		1,392
CECONY		141		3,771,625		—		—		441		84,940,000		582

(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 March 31, 2012, 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	$	245		$	143
Collateral posted	$	64		$	51
Additional collateral (b) (downgrade one level from current ratings (c))	$	35		$	18
Additional collateral (b) (downgrade to below investment grade from current ratings (c))	$	225	(d)	$	106	(d)

(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 March 31, 2012, would have amounted to an estimated $39 million for Con Edison, including $9 million for CECONY. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) 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.

(d) Derivative instruments that are net assets have been excluded from the table. At March 31, 2012, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of not more than $23 million.

Interest Rate Swaps

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 March 31, 2012 was an unrealized loss of $8 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 months ended March 31, 2012 was immaterial. 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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Note K — 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.

Effective January 1, 2012, the Companies adopted 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 existing disclosure requirements for fair value measurements and make other amendments. For fair value measurements in Level 3, this update requires the Companies to provide a description of the valuation process in place, a quantitative disclosure of unobservable inputs and assumptions used in the measurement as well as a narrative description of the sensitivity of the fair value to changes in unobservable inputs and interrelationships between those inputs. The update also requires the Companies to disclose any transfers between Levels 1 and 2 of fair value hierarchy measurements and the reasons for the transfers.

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Assets and liabilities measured at fair value on a recurring basis as of March 31, 2012 are summarized below.

	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	$	—	$	86	$	4	$	103		$	13		$	(122	)	$	9		$	69		$	26
Other assets (3)		83		83		—		—		105			95			—			—			188			178
Transfer in (5) (6)		—		—		105		95		—			—			—			—			105			95
Transfer out (5) (6)		—		—		—		—		(105	)		(95	)		—			—			(105	)		(95	)
Other assets (3)	$	83	$	83	$	105	$	95	$	—		$	—		$	—		$	—		$	188		$	178
Total	$	85	$	83	$	191	$	99	$	103		$	13		$	(122	)	$	9		$	257		$	204
Derivative liabilities:
Commodity (1)	$	10	$	2	$	316	$	170	$	196		$	26		$	(278	)	$	(55	)	$	244		$	143
Interest rate contract (2)		—		—		—		—		8			—			—			—			8			—
Transfer in (5) (6)		—		—		8		—		—			—			—			—			8			—
Transfer out (5) (6)		—		—		—		—		(8	)		—			—			—			(8	)		—
Interest rate contract (2)	$	—	$	—	$	8	$	—	$	—		$	—		$	—		$	—		$	8		$	—
Total	$	10	$	2	$	324	$	170	$	196		$	26		$	(278	)	$	(55	)	$	252		$	143

(1) A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

(2) See Note J.

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

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

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2011 are summarized below.

	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)	$	3	$	—	$	64		$	8		$	87		$	11		$	(84	)	$	5		$	70		$	24
Other assets (3)		76		76		—			—			99			90			—			—			175			166
Total	$	79	$	76	$	64		$	8		$	186		$	101		$	(84	)	$	5		$	245		$	190
Derivative liabilities:
Commodity	$	12	$	4	$	222		$	122		$	169		$	37		$	(194	)	$	(41	)	$	209		$	122
Transfer in (5) (6) (7)		—		—		26			25			6			6			—			—			32			31
Transfer out (5) (6) (7)		—		—		(6	)		(6	)		(26	)		(25	)		—			—			(32	)		(31	)
Commodity (1)	$	12	$	4	$	242		$	141		$	149		$	18		$	(194	)	$	(41	)	$	209		$	122
Interest rate contract (2)		—		—		—			—			8			—			—			—			8			—
Total	$	12	$	4	$	242		$	141		$	157		$	18		$	(194	)	$	(41	)	$	217		$	122

(1) A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

(2) See Note J.

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

(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, 2010 to less than one year as of December 31, 2011.

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

(Millions of Dollars)	Fair Value of Level 3 at 3/31/2012			Valuation Techniques	Unobservable Inputs
Con Edison
Commodity	$	(93	)	Market approach (1)	Discount for inactive markets and/or illiquid locations (2)
CECONY
Commodity	$	(13	)	Market approach (1)	Discount for inactive markets and/or illiquid locations (2)

(1) The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets and liabilities. The commodity derivatives are valued using quoted prices or internally developed models with observable inputs, adjusted for certain contracts that are traded in inactive markets and/or at illiquid locations. The unobservable inputs used in the Companies’ models do not have a significant impact on the valuation.

(2) Significant increases or decreases in any of these inputs in isolation would have a limited impact on fair value measurement. Generally, a change in the fair value measurement is linearly based on changes in these inputs.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of March 31, 2012 and 2011 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended March 31, 2012
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2012			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of March 31, 2012
Con Edison
Derivatives:
Commodity	$	(62	)	$	(58	)	$	(17	)	$	6	$	—	$	—	$	38	$	—		$	(93	)
Interest rate contract		(8	)		(1	)		—			—		—		—		1		8			—
Other assets (1)		99			3			3			—		—		—		—		(105	)		—
Total	$	29		$	(56	)	$	(14	)	$	6	$	—	$	—	$	39	$	(97	)	$	(93	)
CECONY
Derivatives:
Commodity	$	(7	)	$	(5	)	$	(7	)	$	6	$	—	$	—	$	—	$	—		$	(13	)
Other assets (1)		90			3			2			—		—		—		—		(95	)		—
Total	$	83		$	(2	)	$	(5	)	$	6	$	—	$	—	$	—	$	(95	)	$	(13	)

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

33

	For the Three Months Ended March 31, 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 March 31, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	9		$	40	$	10	$	—	$	—	$	3		$	(5	)	$	(31	)
Interest rate contract		(10	)		(1	)		—		—		—		—		1			—			(10	)
Other assets (1)		101			2			2		—		—		—		—			—			105
Total	$	3		$	10		$	42	$	10	$	—	$	—	$	4		$	(5	)	$	64
CECONY
Derivatives:
Commodity	$	(26	)	$	(1	)	$	27	$	10	$	—	$	—	$	(3	)	$	(5	)	$	2
Other assets (1)		92			2			1		—		—		—		—			—			95
Total	$	66		$	1		$	28	$	10	$	—	$	—	$	(3	)	$	(5	)	$	97

(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. See Note A to the financial statements in Item 8 of the Form 10-K. 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 ($3 million loss and $12 million loss) and purchased power costs ($43 million loss and $27 million gain) on the consolidated income statement for the three months ended March 31, 2012 and 2011, respectively. The change in fair value relating to Level 3 commodity derivative assets held at March 31, 2012 and 2011 is included in non-utility revenues ($3 million loss and $12 million loss), and purchased power costs ($7 million loss and $29 million gain) on the consolidated income statement for the three months ended March 31, 2012 and 2011, respectively.

The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At March 31, 2012, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. To assess nonperformance 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 (for an asset) or the Companies’ (for a liability) credit default swaps rates.

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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 First 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). This MD&A 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 management’s discussion and analysis about CECONY applies to Con Edison.

This MD&A should be read in conjunction with the First 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, 2011 (File Nos. 1-14514 and 1-1217, the Form 10-K).

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 retail and wholesale 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 22,000 MMlbs of steam annually to approximately 1,735 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 retail and wholesale customers, sales of certain energy-related products and services, and participation in energy infrastructure projects. At March 31, 2012, Con Edison’s equity investment in its competitive energy businesses was $343 million and their assets amounted to $837 million.

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

	Three months ended March 31, 2012										At March 31, 2012
(millions of dollars, except percentages)	Operating Revenues					Net Income for Common Stock					Assets
CECONY	$	2,561		83	%	$	273		99	%	$	35,755	90	%
O&R		210		7	%		20		7	%		2,455	6	%
Total Utilities		2,771		90	%		293		106	%		38,210	96	%
Con Edison Solutions (a)		277		9	%		(13	)	(5	)%		328	1	%
Con Edison Energy (a)		30		1	%		—		—	%		109	—	%
Con Edison Development		5		—	%		1		—	%		520	1	%
Other (b)		(5	)	—	%		(4	)	(1	)%		534	2	%
Total Con Edison	$	3,078		100	%	$	277		100	%	$	39,701	100	%

(a) Net income from the competitive energy businesses for the three months ended March 31, 2012 includes $18 million of net after-tax mark-to-market losses (Con Edison Solutions, $17 million and Con Edison Energy, $1 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 March 31, 2012 was $277 million or $0.95 a share ($0.94 on a diluted basis) compared with $311 million or $1.07 a share ($1.06 on a diluted basis) for the three months ended March 31, 2011. See “Results of Operations – Summary,” below. For segment financial information, see Note I to the First Quarter Financial Statements and “Results of Operations,” below.

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Results of Operations — Summary

Net income for common stock for the three months ended March 31, 2012 and 2011 was as follows:

(millions of dollars)	2012			2011
CECONY	$	273		$	268
O&R		20			19
Competitive energy businesses (a)		(12	)		27
Other (b)		(4	)		(3	)
Con Edison	$	277		$	311

(a) Includes $(18) million and $22 million of net after-tax mark-to-market (losses)/gains in the three months ended 2012 and 2011, respectively.

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

The Companies’ results of operations for the three months ended March 31, 2012, as compared with 2011, reflect changes in the Utilities’ rate plans and the effects of the milder winter weather on steam revenues. 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 due to pensions, other postretirement benefits and healthcare costs, offset in part by lower operating costs attributable to the milder winter in the 2012 period. Depreciation was higher in the 2012 period reflecting primarily the impact from higher utility plant balances.

The following table presents the estimated effect on earnings per share and net income for common stock for the three months ended 2012 as compared with the 2011 period, resulting from these and other major factors:

	Earnings per Share			Net Income for Common Stock (millions of dollars)
CECONY
Rate plans, primarily to recover increases in certain costs	$	0.12		$	37
Operations and maintenance expenses		(0.10	)		(29	)
Depreciation		(0.03	)		(8	)
Other		0.02			5
Total CECONY		0.01			5
O&R		—			1
Competitive energy businesses (a)		(0.13	)		(39	)
Other, including parent company expenses		—			(1	)
Total variations	$	(0.12	)	$	(34	)

(a) These variations reflect after-tax net mark-to-market losses of $18 million or $0.06 a share in the first quarter of 2012 and after-tax net mark-to-market gains of $22 million or $0.08 a share in the first quarter of 2011.

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

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 three months ended March 31, 2012 and 2011 are summarized as follows:

Con Edison

(millions of dollars)	2012			2011			Variance
Operating activities	$	402		$	362		$	40
Investing activities		(490	)		(496	)		6
Financing activities		209			312			(103	)
Net change		121			178			(57	)
Balance at beginning of period		648			338			310
Balance at end of period	$	769		$	516		$	253

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CECONY

(millions of dollars)	2012			2011			Variance
Operating activities	$	368		$	72		$	296
Investing activities		(487	)		(413	)		(74	)
Financing activities		222			291			(69	)
Net change		103			(50	)		153
Balance at beginning of period		372			78			294
Balance at end of period	$	475		$	28		$	447

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 losses. Principal non-cash credits include amortizations of certain net regulatory liabilities. 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 three months ended March 31, 2012 for Con Edison and CECONY were $40 million and $296 million higher, respectively, than in the 2011 period. The increases in net cash flows reflect primarily the timing of CECONY pension contributions ($184 million in the 2012 period as compared with $491 million in the 2011 period). See Note E to the First Quarter Financial Statements. The increases were offset in part by higher cash collateral paid to brokers and counterparties in the 2012 period ($85 million for Con Edison and $37 million for CECONY).

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.

The changes in regulatory assets principally reflect changes in deferred pension costs in accordance with the accounting rules for retirement benefits. See Note B to the First Quarter Financial Statements.

Cash Flows Used in Investing Activities

Net cash flows used in investing activities for Con Edison and CECONY were $6 million lower and $74 million higher, respectively, for the three months ended March 31, 2012 compared with the 2011 period. The changes for Con Edison and CECONY reflect increased utility construction expenditures in 2012. In addition, for Con Edison, the change reflects the return of investment resulting from the receipt of government grant proceeds at the Pilesgrove solar project and lower non-utility construction expenditures.

Cash Flows from Financing Activities

Net cash flows from financing activities for Con Edison and CECONY were $103 million and $69 million lower, respectively, in the three months ended March 31, 2012 compared with the 2011 period.

In March 2012, CECONY issued $400 million of 4.20 percent 30-year debentures, $239 million of the net proceeds from the sale of which were used to redeem on May 1, 2012 all outstanding shares of its $5

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Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value). The Companies had no issuances of long-term debt in 2011.

Cash flows from financing activities of the Companies also reflect commercial paper issuance. The commercial paper amounts outstanding at March 31, 2012 and 2011 and the average daily balances for the three months ended March 31, 2012 and 2011 for Con Edison and CECONY were as follows:

	2012						2011
(millions of dollars, except Weighted Average Yield)	Outstanding at March 31			Daily average			Outstanding at March 31			Daily average
Con Edison	$	—		$	14		$	464		$	140
CECONY	$	—		$	14		$	464		$	140
Weighted average yield		—	%		0.3	%		0.3	%		0.3	%

Other Changes in Assets and Liabilities

The following table shows changes in certain assets and liabilities at March 31, 2012, compared with December 31, 2011.

	Con Edison			CECONY
(millions of dollars)	2012 vs. 2011 Variance			2012 vs. 2011 Variance
Assets
Prepayments	$	286		$	287
Regulatory asset – Unrecognized pension and other postretirement costs		(258	)		(217	)
Liabilities
Pension and retiree benefits	$	(230	)	$	(195	)

Prepayments

The increase in prepayments for Con Edison and CECONY reflects primarily CECONY’s January 2012 payment of its New York City semi-annual property taxes, offset by three months of amortization, while the December 2011 balance reflects the amortization of the previous semi-annual prepayment. See “Cash Flows from Operating Activities,” above.

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 costs and the noncurrent liability for pension and retiree benefits reflects the final actuarial valuation of the pension and other retiree benefit plans as measured at December 31, 2011 in accordance with the accounting rules for retirement benefits. The change in the regulatory asset also reflects the year’s amortization of accounting costs. The decrease in the noncurrent liability for pension and retiree benefits reflects in part contributions to the plans made by the Utilities in 2012. See Notes B, E and F to the First Quarter Financial Statements.

Capital Requirements and Resources

As of March 31, 2012, there was no material change in the Companies’ capital requirements, contractual obligations and capital resources compared to those disclosed under “Capital Requirements and Resources” in Item 1 of the Form 10-K other than as described in Note C to the First Quarter Financial Statements.

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For each of the Companies, the ratio of earnings to fixed charges (Securities and Exchange Commission basis) for the three months ended March 31, 2012 and 2011 and the twelve months ended December 31, 2011 was:

	Ratio of Earnings to Fixed Charges
	For the Three Months Ended March 31, 2012		For the Three Months Ended March 31, 2011		For the Twelve Months Ended December 31, 2011
Con Edison		3.5		3.9		3.6
CECONY		3.9		3.9		3.8

For each of the Companies, the common equity ratio at March 31, 2012 and December 31, 2011 was:

	Common Equity Ratio (Percent of total capitalization)
	March 31, 2012		December 31, 2011
Con Edison		53.5		52.5
CECONY		53.1		52.0

Regulatory Matters

CECONY’s current electric rate plan covers the three-year period ending March 31, 2013. Either the company or the New York State Public Service Commission (NYSPSC) can initiate a proceeding for a new rate plan. A new rate plan filed by the company would take effect automatically in approximately 11 months unless prior to such time the NYSPSC adopts a rate plan. CECONY understands that the base rates determined pursuant to the current rate plan and the other provisions of the current rate plan would continue in effect after March 31, 2013 until a new rate plan is effective. CECONY is evaluating when it will request a new rate plan in light of, among other things, the return on common equity that the company estimates it could earn after March 31, 2013 under the current rate plan as compared to under a new rate plan. In either case, CECONY expects that the earned return on common equity of its electric business for the rate year ending March 31, 2014 would be less than for the rate year ending March 31, 2013.

For information about a March 2012 NYSPSC order relating to a surcharge that CECONY was to have collected from customers and O&R’s February 2012 Joint Proposal with respect to its rates for electric service rendered in New York, see Note B to the First Quarter Financial Statements.

Financial and Commodity Market Risks

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

Interest Rate Risk

The interest rate risk relates primarily to variable rate debt and to new debt financing needed to fund capital requirements, including the construction expenditures of the Utilities and maturing debt securities. Con Edison and its businesses manage interest rate risk through the issuance of mostly fixed-rate debt with varying maturities and through opportunistic refinancing of debt. Con Edison and CECONY estimate that at March 31, 2012, a 10 percent variation in interest rates applicable to its variable rate debt would not result in a material change in annual interest expense. Under CECONY’s current gas, steam and electric rate plans, variations in actual long-term debt interest rates are reconciled to levels reflected in rates. Under O&R’s current New York rate plans, variations in actual interest expense are reconciled to the level set in rates.

In addition, from time to time, Con Edison and its businesses enter into derivative financial instruments to hedge interest rate risk on certain debt securities. See “Interest Rate Swaps” in Note J to the First 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 J to the First Quarter Financial Statements.

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Con Edison estimates that, as of March 31, 2012, a 10 percent decline in market prices would result in a decline in fair value of $47 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $39 million is for CECONY and $8 million is for O&R. Con Edison expects that any such change in fair value would be largely offset by directionally opposite changes in the cost of the electricity and gas purchased. In accordance with provisions approved by state regulators, the Utilities generally recover from customers the costs they incur for energy purchased for their customers, including gains and losses on certain derivative instruments used to hedge energy purchased and related costs.

Con Edison’s competitive energy businesses use a value-at-risk (VaR) model to assess the market 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 three months ended March 31, 2012 and the year ended December 31, 2011, respectively, was as follows:

95% Confidence Level, One-Day Holding Period	March 31, 2012		December 31, 2011
	(millions of dollars)
Average for the period	$	1	$	1
High		1		1
Low		1		—

Credit Risk

The Companies are exposed to credit risk related to transactions entered into primarily for the various energy supply and hedging activities by the Utilities and the competitive energy businesses. 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 J to the First Quarter Financial Statements.

Investment Risk

The Companies’ investment risk relates to the investment of plan assets for their pension and other postretirement benefit plans. The Companies’ current investment policy for pension plan assets includes investment targets of 60 percent equities and 40 percent fixed income and other securities. At March 31, 2012, the pension plan investments consisted of 63 percent equity and 37 percent fixed income and other securities.

Material Contingencies

For information concerning potential liabilities arising from the Companies’ material contingencies, see Notes B, G, and H to the First 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 assumed when rates were approved. Delivery revenues for CECONY’s steam business and O&R’s businesses

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in New Jersey and Pennsylvania are affected by changes in delivery volumes resulting from weather, economic conditions and other factors. See Note B to the First Quarter Financial Statements.

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 utility activities, O&R’s regulated utility activities and Con Edison’s competitive energy businesses. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. A discussion of the results of operations by principal business segment for the three months ended March 31, 2012 and 2011 follows. For additional business segment financial information, see Note I to the First Quarter Financial Statements.

Three Months Ended March 31, 2012 Compared with Three Months Ended March 31, 2011

The Companies’ results of operations (which were discussed above under “Results of Operations – Summary”) in 2012 compared with 2011 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	$	(148	)		(5.5	)%	$	(31	)		(12.9	)%	$	(92	)		(23.1	)%	$	(271	)		(8.1	)%
Purchased power		(36	)		(7.5	)		(28	)		(41.2	)		(20	)		(6.4	)		(84	)		(9.7	)
Fuel		(68	)		(38.6	)		N/A			N/A			—			—			(68	)		(38.6	)
Gas purchased for resale		(94	)		(35.7	)		(13	)		(33.3	)		(5	)		(83.3	)		(112	)		(36.4	)
Operating revenues less purchased power, fuel and gas purchased for resale (net revenues)		50			2.8			10			7.5			(67	)		(84.8	)		(7	)		(0.4	)
Operations and maintenance		48			8.0			6			8.5			(3	)		(10.0	)		51			7.3
Depreciation and amortization		14			6.9			1			8.3			—			—			15			6.9
Taxes, other than income taxes		(10	)		(2.3	)		3			23.1			(1	)		(20.0	)		(8	)		(1.7	)
Operating income		(2	)		(0.4	)		—			—			(63	)		Large			(65	)		(10.4	)
Other income less deductions		(3	)		(60.0	)		(1	)		Large			(2	)		(66.7	)		(6	)		(66.7	)
Net interest expense		1			0.7			(2	)		(20.0	)		(1	)		(14.3	)		(2	)		(1.3	)
Income before income tax expense		(6	)		(1.4	)		1			3.4			(64	)		Large			(69	)		(14.3	)
Income tax expense		(11	)		(7.6	)		—			—			(24	)		Large			(35	)		(20.7	)
Net income for common stock	$	5			1.8	%	$	1			5.3	%	$	(40	)		Large		$	(34	)		(10.9	)%

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

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

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CECONY

	Three Months Ended March 31, 2012								Three Months Ended March 31, 2011
(millions of dollars)	Electric		Gas		Steam		2012 Total		Electric		Gas		Steam		2011 Total		2012-2011 Variation
Operating revenues	$	1,735	$	563	$	263	$	2,561	$	1,721	$	663	$	325	$	2,709	$	(148	)
Purchased power		432		—		15		447		464		—		19		483		(36	)
Fuel		50		—		58		108		76		—		100		176		(68	)
Gas purchased for resale		—		169		—		169		—		263		—		263		(94	)
Net revenues		1,253		394		190		1,837		1,181		400		206		1,787		50
Operations and maintenance		517		82		46		645		459		103		35		597		48
Depreciation and amortization		173		29		16		218		161		27		16		204		14
Taxes, other than income taxes		339		62		29		430		344		66		30		440		(10	)
Operating income	$	224	$	221	$	99	$	544	$	217	$	204	$	125	$	546	$	(2	)

Electric

CECONY’s results of electric operations for the three months ended March 31, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	March 31, 2012		March 31, 2011		Variation
Operating revenues	$	1,735	$	1,721	$	14
Purchased power		432		464		(32	)
Fuel		50		76		(26	)
Net revenues		1,253		1,181		72
Operations and maintenance		517		459		58
Depreciation and amortization		173		161		12
Taxes, other than income taxes		339		344		(5	)
Electric operating income	$	224	$	217	$	7

CECONY’s electric sales and deliveries, excluding off-system sales, for the three months ended March 31, 2012 compared with the 2011 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	March 31, 2012		March 31, 2011		Variation			Percent Variation			March 31, 2012			March 31, 2011			Variation			Percent Variation
Residential/Religious (a)		2,411		2,664		(253	)		(9.5	)%	$	588		$	648		$	(60	)		(9.3	)%
Commercial/Industrial		2,384		2,860		(476	)		(16.6	)		440			561			(121	)		(21.6	)
Retail access customers		5,903		5,558		345			6.2			591			474			117			24.7
NYPA, Municipal Agency and other sales		2,690		2,774		(84	)		(3.0	)		125			117			8			6.8
Other operating revenues		—		—		—			—			(9	)		(79	)		70			88.6
Total		13,388		13,856		(468	)		(3.4	)%	$	1,735		$	1,721		$	14			0.8	%

(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 $14 million in the three months ended March 31, 2012 compared with the 2011 period due primarily to higher revenues from the electric rate plan ($73 million), offset in part by lower purchased power ($32 million) and fuel costs ($26 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

43

accordance with the revenue decoupling mechanism and other provisions of the company’s rate plan.

Electric delivery volumes in CECONY’s service area decreased 3.4 percent in the three months ended March 31, 2012 compared with the 2011 period. After adjusting for variations, principally weather and billing days, electric delivery volumes in CECONY’s service area decreased 0.8 percent in the three months ended March 31, 2012 compared with the 2011 period reflecting lower average use per customer.

CECONY’s electric purchased power costs decreased $32 million in the three months ended March 31, 2012 compared with the 2011 period due to a decrease in purchased volumes ($51 million), offset by an increase in unit costs ($19 million). Electric fuel costs decreased $26 million in the three months ended March 31, 2012 compared with the 2011 period due to lower unit costs ($20 million) and sendout volumes from the company’s electric generating facilities ($6 million).

CECONY’s electric operating income increased $7 million in the three months ended March 31, 2012 compared with the 2011 period. The increase reflects primarily higher net revenues ($72 million, due primarily to the electric rate plan) and lower taxes, other than income taxes ($5 million, principally property taxes). The higher net revenues were offset by higher operations and maintenance costs ($58 million, due primarily to higher pension expense ($38 million), employees’ health care costs ($6 million)), injuries and damages ($6 million) and higher depreciation and amortization ($12 million). See “Regulatory Assets and Liabilities” in Note B to the First Quarter Financial Statements.

Gas

CECONY’s results of gas operations for the three months ended March 31, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	March 31, 2012		March 31, 2011		Variation
Operating revenues	$	563	$	663	$	(100	)
Gas purchased for resale		169		263		(94	)
Net revenues		394		400		(6	)
Operations and maintenance		82		103		(21	)
Depreciation and amortization		29		27		2
Taxes, other than income taxes		62		66		(4	)
Gas operating income	$	221	$	204	$	17

CECONY’s gas sales and deliveries, excluding off-system sales, for the three months ended March 31, 2012 compared with the 2011 period were:

	Thousands of dths Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	March 31, 2012		March 31, 2011		Variation			Percent Variation			March 31, 2012			March 31, 2011			Variation			Percent Variation
Residential		14,608		18,783		(4,175	)		(22.2	)%	$	260		$	326		$	(66	)		(20.2	)%
General		11,136		13,250		(2,114	)		(16.0	)		120			152			(32	)		(21.1	)
Firm transportation		21,759		24,096		(2,337	)		(9.7	)		159			144			15			10.4
Total firm sales and transportation		47,503		56,129		(8,626	)		(15.4	)		539			622			(83	)		(13.3	)
Interruptible sales (a)		2,142		3,562		(1,420	)		(39.9	)		18			36			(18	)		(50.0	)
NYPA		9,549		5,820		3,729			64.1			1			1			—			—
Generation plants		14,299		12,359		1,940			15.7			7			7			—			—
Other		7,498		7,687		(189	)		(2.5	)		12			19			(7	)		(36.8	)
Other operating revenues		—		—		—						(14	)		(22	)		8			36.4
Total		80,991		85,557		(4,566	)		(5.3	)%	$	563		$	663		$	(100	)		(15.1	)%

(a) Includes 171 and 984 thousands of dths for the 2012 and 2011 period, respectively, which are also reflected in firm transportation and other.

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CECONY’s gas operating revenues decreased $100 million in the three months ended March 31, 2012 compared with the 2011 period due primarily to a decrease in gas purchased for resale costs ($94 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 plan.

CECONY’s sales and transportation volumes for firm customers decreased 15.4 percent in the three months ended March 31, 2012 compared with the 2011 period. After adjusting for variations, principally weather and billing days, firm gas sales and transportation volumes in the company’s service area increased 0.9 percent in the three months ended March 31, 2012.

CECONY’s purchased gas cost decreased $94 million in the three months ended March 31, 2012 compared with the 2011 period due to lower sendout volumes ($69 million) and unit costs ($25 million).

CECONY’s gas operating income increased $17 million in the three months ended March 31, 2012 compared with the 2011 period. The increase reflects primarily lower operations and maintenance costs ($21 million, due primarily to a decrease in the surcharge for New York State regulatory assessments ($12 million) and lower taxes, other than incomes taxes ($4 million, principally property taxes and local taxes), offset by lower net revenues ($6 million) and higher depreciation ($2 million).

Steam

CECONY’s results of steam operations for the three months ended March 31, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	March 31, 2012		March 31, 2011		Variation
Operating revenues	$	263	$	325	$	(62	)
Purchased power		15		19		(4	)
Fuel		58		100		(42	)
Net revenues		190		206		(16	)
Operations and maintenance		46		35		11
Depreciation and amortization		16		16		—
Taxes, other than income taxes		29		30		(1	)
Steam operating income	$	99	$	125	$	(26	)

CECONY’s steam sales and deliveries for the three months ended March 31, 2012 compared with the 2011 period were:

	Millions of Pounds Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	March 31, 2012		March 31, 2011		Variation			Percent Variation			March 31, 2012			March 31, 2011			Variation			Percent Variation
General		245		334		(89	)		(26.6	)%	$	12		$	15		$	(3	)		(20.0	)%
Apartment house		2,072		2,593		(521	)		(20.1	)		71			83			(12	)		(14.5	)
Annual power		4,935		6,541		(1,606	)		(24.6	)		193			234			(41	)		(17.5	)
Other operating revenues		—		—		—			—			(13	)		(7	)		(6	)		(85.7	)
Total		7,252		9,468		(2,216	)		(23.4	)%	$	263		$	325		$	(62	)		(19.1	)%

CECONY’s steam operating revenues decreased $62 million in the three months ended March 31, 2012 compared with the 2011 period due primarily to lower fuel costs ($42 million), the net change in rates under the steam rate plan ($14 million) and lower purchased power costs ($4 million). Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan.

Steam sales and delivery volumes decreased 23.4 percent in the three months ended March 31, 2012 compared with the 2011 period reflecting milder winter weather. After adjusting for variations, principally weather and billing days, steam sales and deliveries decreased 1.2 percent in the three months ended March 31, 2012, reflecting lower average normalized use per customer.

45

CECONY’s steam fuel costs decreased $42 million in the three months ended March 31, 2012 compared with the 2011 period due to lower unit costs ($25 million) and sendout volumes ($17 million). Steam purchased power costs decreased $4 million in the three months ended March 31, 2012 compared with the 2011 period due to a decrease in unit costs ($2 million) and purchased volumes ($2 million).

Steam operating income decreased $26 million in the three months ended March 31, 2012 compared with the 2011 period. The decrease reflects primarily lower net revenues ($16 million) and higher operations and maintenance costs ($11 million, due primarily to higher pension expense ($16 million)), offset by lower taxes, other than income taxes ($1 million, principally local taxes).

Income Taxes

Income taxes decreased $11 million in the three months ended March 31, 2012 compared with the 2011 period due primarily to higher deductions for injuries and damages payments in the 2012 period.

O&R

	Three Months Ended March 31, 2012						Three Months Ended March 31, 2011
(millions of dollars)	Electric		Gas		2012 Total		Electric		Gas		2011 Total		2012-2011 Variation
Operating revenues	$	128	$	82	$	210	$	149	$	92	$	241	$	(31	)
Purchased power		40		—		40		68		—		68		(28	)
Gas purchased for resale		—		26		26		—		39		39		(13	)
Net revenues		88		56		144		81		53		134		10
Operations and maintenance		59		18		77		53		18		71		6
Depreciation and amortization		9		4		13		9		3		12		1
Taxes, other than income taxes		12		4		16		9		4		13		3
Operating income	$	8	$	30	$	38	$	10	$	28	$	38	$	—

Electric

O&R’s results of electric operations for the three months ended March 31, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	March 31, 2012		March 31, 2011		Variation
Operating revenues	$	128	$	149	$	(21	)
Purchased power		40		68		(28	)
Net revenues		88		81		7
Operations and maintenance		59		53		6
Depreciation and amortization		9		9		—
Taxes, other than income taxes		12		9		3
Electric operating income	$	8	$	10	$	(2	)

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O&R’s electric sales and deliveries, excluding off-system sales, for the three months ended March 31, 2012 compared with the 2011 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	March 31, 2012		March 31, 2011		Variation			Percent Variation			March 31, 2012		March 31, 2011			Variation			Percent Variation
Residential/Religious (a)		375		429		(54	)		(12.6	)%	$	58	$	74		$	(16	)		(21.6	)%
Commercial/Industrial		243		316		(73	)		(23.1	)		28		41			(13	)		(31.7	)
Retail access customers		689		625		64			10.2			37		33			4			12.1
Public authorities		28		25		3			12.0			2		3			(1	)		(33.3	)
Other operating revenues		—		—		—			—			3		(2	)		5			Large
Total		1,335		1,395		(60	)		(4.3	)%	$	128	$	149		$	(21	)		(14.1	)%

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

O&R’s electric operating revenues decreased $21 million in the three months ended March 31, 2012 compared with the 2011 period due primarily to lower purchased power costs ($28 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 decoupling mechanism, and as a result, changes in such volumes do impact such 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 First Quarter Financial Statements.

Electric delivery volumes in O&R’s service area decreased 4.3 percent in the three months ended March 31, 2012 compared with the 2011 period. After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased 2.0 percent in the three months ended March 31, 2012 compared with the 2011 period.

Electric operating income decreased $2 million in the three months ended March 31, 2012 compared with the 2011 period. The decrease reflects primarily higher operations and maintenance costs ($6 million, due to higher pension expense and other postretirement costs) and taxes other than income taxes ($3 million, principally property taxes), offset by higher net revenues ($7 million).

Gas

O&R’s results of gas operations for the three months ended March 31, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	March 31, 2012		March 31, 2011		Variation
Operating revenues	$	82	$	92	$	(10	)
Gas purchased for resale		26		39		(13	)
Net revenues		56		53		3
Operations and maintenance		18		18		—
Depreciation and amortization		4		3		1
Taxes, other than income taxes		4		4		—
Gas operating income	$	30	$	28	$	2

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O&R’s gas sales and deliveries, excluding off-system sales, for the three months ended March 31, 2012 compared with the 2011 period were:

	Thousands of dths Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	March 31, 2012		March 31, 2011		Variation			Percent Variation			March 31, 2012		March 31, 2011			Variation			Percent Variation
Residential		2,856		3,774		(918	)		(24.3	)%	$	39	$	53		$	(14	)		(26.4	)%
General		561		737		(176	)		(23.9	)		7		9			(2	)		(22.2	)
Firm transportation		4,368		5,296		(928	)		(17.5	)		31		31			—			—
Total firm sales and transportation		7,785		9,807		(2,022	)		(20.6	)		77		93			(16	)		(17.2	)
Interruptible sales		1,309		1,311		(2	)		(0.2	)		1		1			—			—
Generation plants		—		98		(98	)		Large			—		—			—			—
Other		339		399		(60	)		(15.0	)		—		—			—			—
Other gas revenues		—		—		—			—			4		(2	)		6			Large
Total		9,433		11,615		(2,182	)		(18.8	)%	$	82	$	92		$	(10	)		(10.9	)%

O&R’s gas operating revenues decreased $10 million in the three months ended March 31, 2012 compared with the 2011 period due primarily to the decrease in gas purchased for resale in 2012 ($13 million), offset in part by the gas rate plan.

Sales and transportation volumes for firm customers decreased 20.6 percent in the three months ended March 31, 2012 compared with the 2011 period. After adjusting for weather and other variations, total firm sales and transportation volumes increased 2.1 percent in the three months ended March 31, 2012 compared with the 2011 period. O&R’s New York revenues from gas sales are subject to a weather normalization clause that moderates, but does not eliminate, the effect of weather-related changes on net income.

Gas operating income increased $2 million in the three months ended March 31, 2012 compared with the 2011 period. The increase reflects primarily higher net revenues ($3 million), offset by higher depreciation ($1 million).

Competitive Energy Businesses

The competitive energy businesses’ results of operations for the three months ended March 31, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	March 31, 2012			March 31, 2011		Variation
Operating revenues	$	310		$	408	$	(98	)
Purchased power		295			321		(26	)
Gas purchased for resale		1			6		(5	)
Net revenues		14			81		(67	)
Operations and maintenance		27			30		(3	)
Depreciation and amortization		2			2		—
Taxes, other than income taxes		5			5		—
Operating income	$	(20	)	$	44	$	(64	)

The competitive energy businesses’ operating revenues decreased $98 million in the three months ended March 31, 2012 compared with the 2011 period, due primarily to lower electric retail and wholesale revenues. Electric wholesale revenues decreased $39 million in the three months ended March 31, 2012 as compared with the 2011 period, due to lower sales volumes ($25 million) and unit prices ($14 million). Electric retail revenues decreased $63 million, due to lower per unit prices ($33 million) and sales volume ($30 million). Gross profit on electric retail revenues decreased due primarily to lower volumes, offset in part by higher unit gross margins. Net mark-to-market values decreased $69 million in the three months ended

48

March 31, 2012 as compared with the 2011 period, of which $77 million in losses are reflected in purchased power costs and $9 million in gains are reflected in revenues. Other revenues decreased $5 million in the three months ended March 31, 2012 as compared with the 2011 period due primarily to lower energy services revenue.

Purchased power costs decreased $26 million in the three months ended March 2012 compared with the 2011 period, due primarily to lower purchased power costs of $103 million and changes in mark-to-market values of $77 million. Purchased power costs decreased $103 million due to lower unit prices ($58 million) and volumes ($45 million). Operating income decreased $64 million in the three months ended March 31, 2012 compared with the 2011 period due primarily to net mark-to-market effects ($69 million), partially offset by higher revenue from solar generating facilities and wholesale gross profit.

Other

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

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Item 3: Quantitative and Qualitative Disclosures About Market Risk

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

Item 4: Controls and Procedures

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

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

The Utilities are undertaking a project with the objective of improving business processes and information systems. The Utilities expect the project to reduce costs, improve support of operating activities, reduce financial reporting risks, and simplify compliance activities. The focus of the project is the implementation of new financial and supply-chain enterprise resource planning information systems. The Utilities 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.

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Part II Other Information

Item 1: Legal Proceedings

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

Item 1A: Risk Factors

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

Item 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
January 1, 2012 to January 31, 2012		132,747	$	59.33		—		—
February 1, 2012 to February 29, 2012		88,902		59.07		—		—
March 1, 2012 to March 31, 2012		99,494		58.22		—		—
Total		321,143	$	58.91		—		—

* 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 three-month periods ended March 31, 2012 and 2011, and the 12-month period ended December 31, 2011.
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 10.2	Amendment Number 4, dated January 1, 2011, to the Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan.
Exhibit 12.2	Statement of computation of CECONY’s ratio of earnings to fixed charges for the three-month periods ended March 31, 2012 and 2011, and the 12-month period ended December 31, 2011.
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: May 3, 2012	By	/s/    Robert Hoglund
		Robert Hoglund Senior Vice President, Chief Financial Officer and Duly Authorized Officer

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EX-12.1

Exhibit 12.1

Consolidated Edison, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Three Months Ended March 31, 2012		For the Twelve Months Ended December 31, 2011		For the Three Months Ended March 31, 2011
Earnings
Net Income for Common Stock	$	277	$	1,051	$	311
Preferred Stock Dividend		3		11		3
(Income) or Loss from Equity Investees		1		—		2
Minority Interest Loss		—		—		—
Income Tax		134		600		169
Pre-Tax Income for Common Stock	$	415	$	1,662	$	485
Add: Fixed Charges*		161		642		165
Add: Distributed Income of Equity Investees		—		—		—
Subtract: Interest Capitalized		—		—		—
Subtract: Pre-Tax Preferred Stock Dividend Requirement		5		19		5
Earnings	$	571	$	2,285	$	645
* Fixed Charges
Interest on Long-term Debt	$	141	$	562	$	141
Amortization of Debt Discount, Premium and Expense		4		20		6
Interest Capitalized		—		—		—
Other Interest		5		18		7
Interest Component of Rentals		6		23		6
Pre-Tax Preferred Stock Dividend Requirement		5		19		5
Fixed Charges	$	161	$	642	$	165
Ratio of Earnings to Fixed Charges		3.5		3.6		3.9

EX-31.1.1

Exhibit 31.1.1

CERTIFICATIONS

I, Kevin Burke, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2012 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: May 3, 2012

/s/ Kevin Burke

Kevin Burke

Chairman, President and Chief Executive Officer

EX-31.1.2

Exhibit 31.1.2

CERTIFICATIONS

I, Robert Hoglund, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2012 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: May 3, 2012

/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 March 31, 2012, 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: May 3, 2012

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 March 31, 2012, 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: May 3, 2012

EX-10.2

Exhibit 10.2

AMENDMENT #4

TO THE

CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

2005 EXECUTIVE INCENTIVE PLAN

Effective January 1, 2011

Pursuant to the resolutions adopted by the Board of Directors of Consolidated Edison, Inc., at a meeting duly held on July 15, 2010, the undersigned hereby approves effective January 1, 2011, the amendment set forth below to the Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan, as set forth below:

1. The PURPOSE is amended by adding the following at the end thereof:

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

2. ARTICLE V. PAYMENT OF AWARDS is amended as follows:

A new Section 5.04 is added as follows:

5.04  Recoupment of Awards

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

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

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

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

1

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

IN WITNESS WHEREOF, the undersigned has executed this instrument this 29^th day of February, 2012.

/s/ Mary Adamo

Plan Administrator,

Consolidated Edison Company of New York, Inc.

2005 Executive Incentive Plan

and

Vice President – Human Resources

Consolidated Edison Company of New York, Inc.

2

EX-12.2

Exhibit 12.2

Consolidated Edison Company of New York, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Three Months Ended March 31, 2012		For the Twelve Months Ended December 31, 2011		For the Three Months Ended March 31, 2011
Earnings
Net Income for Common Stock	$	273	$	978	$	268
Preferred Stock Dividend		3		11		3
(Income) or Loss from Equity Investees		—		—		—
Minority Interest Loss		—		—		2
Income Tax		134		558		145
Pre-Tax Income for Common Stock	$	410	$	1,547	$	418
Add: Fixed Charges*		141		561		142
Add: Distributed Income of Equity Investees		—		—		—
Subtract: Interest Capitalized		—		—		—
Subtract: Pre-Tax Preferred Stock Dividend Requirement		—		—		—
Earnings	$	551	$	2,108	$	560
* Fixed Charges
Interest on Long-term Debt	$	127	$	505	$	126
Amortization of Debt Discount, Premium and Expense		4		18		6
Interest Capitalized		—		—		—
Other Interest		5		16		5
Interest Component of Rentals		5		22		5
Pre-Tax Preferred Stock Dividend Requirement		—		—		—
Fixed Charges	$	141	$	561	$	142
Ratio of Earnings to Fixed Charges		3.9		3.8		3.9

EX-31.2.1

Exhibit 31.2.1

CERTIFICATIONS

I, Kevin Burke, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2012 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: May 3, 2012

/a/ Kevin Burke

Kevin Burke

Chairman and Chief Executive Officer

EX-31.2.2

Exhibit 31.2.2

CERTIFICATIONS

I, Robert Hoglund, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2012 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: May 3, 2012

/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 March 31, 2012, 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: May 3, 2012

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 March 31, 2012, 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: May 3, 2012

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Environmental Matters (Environmental Remediation Costs) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Environmental Matters [Abstract]
Remediation costs incurred	$ 7	$ 6
Insurance recoveries received

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Derivative Instruments And Hedging Activities (Number Of Derivative Contracts By Commodity Type) (Details)	3 Months Ended
	Mar. 31, 2012
Electric Derivatives [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	754	[1]
MWhs	16,197,114	[2]
Number of Capacity Contracts	59	[1]
MWs	7,639	[2]
Gas Derivatives [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	579	[1]
Number of Capacity Contracts	1,392	[1]
Dths	91,840,940	[2]

[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.

XML

Derivative Instruments And Hedging Activities (Fair Values Of The Companies' Commodity Derivatives) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012		Dec. 31, 2011
Derivatives Assets [Member]
Derivatives, Fair Value [Line Items]
Total derivatives asset	$ 204	[1]	$ 165	[1]
Impact of netting	(134)	[1]	(95)	[1]
Net derivatives asset	70	[1]	70	[1]
Derivatives Assets [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Total derivatives asset	179	[1]	139	[1]
Derivatives Assets [Member] | Other Deferred Charges And Non-Current Assets [Member]
Derivatives, Fair Value [Line Items]
Total derivatives asset	25	[1]	26	[1]
Derivatives Liabilities [Member]
Derivatives, Fair Value [Line Items]
Impact of netting	(290)	[1]	(205)	[1]
Fair value of derivative liabilities	535	[1]	414	[1]
Net derivatives liability	245	[1]	209	[1]
Derivatives Liabilities [Member] | Fair Value Of Derivative Liabilities, Current [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative liabilities	433	[1]	331	[1]
Derivatives Liabilities [Member] | Fair Value Of Derivative Liabilities, Long-Term [Member]
Derivatives, Fair Value [Line Items]
Fair value of derivative liabilities	$ 102	[1]	$ 83	[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.

XML

Regulatory Matters (Regulatory Assets And Liabilities) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Regulatory Assets [Line Items]
Regulatory assets - long-term	$ 9,276	$ 9,337
Regulatory assets - current	192	164
Total Regulatory Assets	9,468	9,501
Regulatory liabilities	846	977
Regulatory liabilities - current	286	118
Total Regulatory Liabilities	1,132	1,095
Unrecognized Pension And Other Postretirement Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	5,594	5,852
Future Income Tax [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	1,840	1,798
Environmental Remediation Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	729	681
Pension And Other Post Retirement Benefits Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	219	198
Revenue Taxes [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	167	163
Surcharge For New York State Assessment [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	143	90
Deferred Storm Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	125	128
Net Electric Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	116	121
Deferred Derivative Losses - Long-Term [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	78	60
O&R Transition Bond Charges [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	43	44
Preferred Stock Redemption [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	30
Workers' Compensation [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	22	23
Property Tax Reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	13	13
Regulatory liabilities	68	35
Recoverable Energy Costs - Long Term [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term		14
Other [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	157	152
Deferred Derivative Losses - Current [Member]
Regulatory Assets [Line Items]
Regulatory assets - current	192	164
Allowance For Cost Of Removal Less Salvage [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	457	448
World Trade Center Settlement Proceeds [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	62	62
Net Unbilled Revenue Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	51	104
Long-Term Interest Rate Reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	42	30
Carrying Charges On Transmission And Distribution Net Plant [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	41	38
Gas Line Losses [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	17	21
Expenditure Prudence Proceeding [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	8	11
Energy Efficiency Programs [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	6	22
Other Liabilities [Member]
Regulatory Assets [Line Items]
Regulatory liabilities	94	206
Electric Surcharge Offset [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	134
Refundable Energy Costs - Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	99	51
Revenue Decoupling Mechanism [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	51	66
Deferred Derivative Gains - Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	$ 2	$ 1

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Pension Benefits (Tables)

3 Months Ended

Mar. 31, 2012

Pension Benefits [Abstract]

Companies' Net Periodic Benefit Costs

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses	$	59		$	47		$	55		$	44
Interest cost on projected benefit obligation		137			140			128			131
Expected return on plan assets		(176	)		(183	)		(168	)		(175	)
Amortization of net actuarial loss		177			132			168			125
Amortization of prior service costs		2			2			2			2
NET PERIODIC BENEFIT COST	$	199		$	138		$	185		$	127
Cost capitalized		(64	)		(48	)		(63	)		(45	)
Cost deferred		(37	)		(51	)		(38	)		(52	)
Cost charged to operating expenses	$	98		$	39		$	84		$	30

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Fair Value Measurements (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Fair Value Measurements [Abstract]
Gain (loss) on Level 3 energy derivative assets	$ (3)
Gains (loss) on Level 3 energy derivative liabilities		(12)
Loss on Level 3 energy derivative assets for purchased power costs	(43)
Gain (loss) on Level 3 energy derivative liabilities for purchased power costs		27
Fair value, assets measured on recurring basis, change in unrealized gain (loss) included in other income	(3)	(12)
Fair value, assets measured on recurring basis, change in unrealized gain (loss) included in purchased power costs	$ (7)	$ 29

XML

Other Material Contingencies (Total Guarantees) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 760	$ 760
Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	707
Intra-Company Guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	16
Other Guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	37
Guarantee Duration, 0 - 3 Years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	685
Guarantee Duration, 0 - 3 Years [Member] | Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	637
Guarantee Duration, 0 - 3 Years [Member] | Intra-Company Guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	15
Guarantee Duration, 0 - 3 Years [Member] | Other Guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	33
Guarantee Duration, 4 - 10 Years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	8
Guarantee Duration, 4 - 10 Years [Member] | Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	4
Guarantee Duration, 4 - 10 Years [Member] | Other Guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	4
Guarantee Duration, Greater Than 10 Years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	67
Guarantee Duration, Greater Than 10 Years [Member] | Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	66
Guarantee Duration, Greater Than 10 Years [Member] | Intra-Company Guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 1

XML

Other Postretirement Benefits (Net Periodic Postretirement Benefit Costs) (Details) (Other Postretirement Benefits [Member], USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Other Postretirement Benefits [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Service cost	$ 7	$ 6
Interest cost on accumulated other postretirement benefit obligation	18	21
Expected return on plan assets	(21)	(22)
Amortization of net actuarial loss	25	22
Amortization of prior service costs	(5)	(2)
Amortization of transition obligation		1
NET PERIODIC POSTRETIREMENT BENEFIT COST	24	26
Cost capitalized	(8)	(9)
Cost charged	7	4
Cost charged to operating expenses	23	21
Expected contributions	$ 87

XML

Fair Value Measurements (Schedule Of Commodity Derivatives) (Details) (Commodity [Member], USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of commodity derivatives	$ (93)
Unobservable Inputs	Discount for inactive markets and/or illiquid locations (2)	[1]
Market Approach [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Valuation Techniques	Market approach (1)	[2]

[1] Significant increases or decreases in any of these inputs in isolation would have a limited impact on fair value measurement. Generally, a change in the fair value measurement is linearly based on changes in these inputs.

[2] The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets and liabilities. The commodity derivatives are valued using quoted prices or internally developed models with observable inputs, adjusted for certain contracts that are traded in inactive markets and/or at illiquid locations. The unobservable inputs used in the Companies' models do not have a significant impact on the valuation.

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Derivative Instruments And Hedging Activities (Changes In The Fair Values Of Commodity Derivatives) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Derivatives, Fair Value [Line Items]
Total deferred gains	$ 1	[1]	$ 9	[1]
Total deferred losses	(120)	[1]	12	[1]
Net deferred losses	(119)	[1]	21	[1]
Total pre-tax gain/(loss) recognized in income	(90)	[1]	(17)	[1]
Purchased Power Expense [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income	(86)	[1],[2]	(21)	[1],[3]
Total pre-tax gain/(loss) recognized in income	(27)		50
Gas Purchased For Resale [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income	(1)	[1]	(6)	[1]
Non-Utility Revenue [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income	(3)	[1],[2]	10	[1],[3]
Total pre-tax gain/(loss) recognized in income	(4)		(13)
Deferred Derivative Gains, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains	1	[1]	6	[1]
Regulatory Liabilities, Long-Term [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains			3	[1]
Deferred Derivative Losses, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred losses	(28)	[1]	44	[1]
Recoverable Energy Costs, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred losses	(74)	[1]	(49)	[1]
Regulatory Assets, Long-Term [Member]
Derivatives, Fair Value [Line Items]
Total deferred losses	$ (18)	[1]	$ 17	[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 March 31, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax loss of $(4) million and $(27) million, respectively.

[3] For the three months ended March 31, 2011, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $50 million, respectively.

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General

3 Months Ended

Mar. 31, 2012

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, 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, 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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Financial Information By Business Segment (Financial Data For The Business Segments) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Segment Reporting Information [Line Items]
Depreciation and amortization	$ 233		$ 218
Operating income	561		626
CECONY [Member]
Segment Reporting Information [Line Items]
Operating revenues	2,561		2,709
Depreciation and amortization	218		204
Operating income	544		546
O&R [Member]
Segment Reporting Information [Line Items]
Operating revenues	210		241
Depreciation and amortization	13		12
Operating income	38		38
Consolidated Edison Inc [Member]
Segment Reporting Information [Line Items]
Operating revenues	3,078		3,349
Depreciation and amortization	233		218
Operating income	561		626
CECONY - Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,735		1,721
Inter-segment revenues	3		3
Depreciation and amortization	173		161
Operating income	224		217
CECONY - Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	563		663
Inter-segment revenues	1		1
Depreciation and amortization	29		27
Operating income	221		204
CECONY - Steam [Member]
Segment Reporting Information [Line Items]
Operating revenues	263		325
Inter-segment revenues	19		20
Depreciation and amortization	16		16
Operating income	99		125
Consolidation Adjustments [Member]
Segment Reporting Information [Line Items]
Inter-segment revenues	(23)		(24)
O&R - Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	128		149
Depreciation and amortization	9		9
Operating income	8		10
O&R - Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	82		92
Depreciation and amortization	4		3
Operating income	30		28
Competitive Energy Businesses [Member]
Segment Reporting Information [Line Items]
Operating revenues	310		408
Inter-segment revenues	2		3
Depreciation and amortization	2		2
Operating income	(20)		44
Other [Member]
Segment Reporting Information [Line Items]
Operating revenues	(3)	[1]	(9)	[1]
Inter-segment revenues	(2)	[1]	(3)	[1]
Operating income	$ (1)	[1]	$ (2)	[1]

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

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Financial Information By Business Segment (Tables)

3 Months Ended

Mar. 31, 2012

Financial Information By Business Segment [Abstract]

Financial Data For The Business Segments

	For the Three Months Ended March 31,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012			2011			2012			2011			2012		2011		2012			2011
CECONY
Electric	$	1,735		$	1,721		$	3		$	3		$	173	$	161	$	224		$	217
Gas		563			663			1			1			29		27		221			204
Steam		263			325			19			20			16		16		99			125
Consolidation adjustments		—			—			(23	)		(24	)		—		—		—			—
Total CECONY	$	2,561		$	2,709		$	—		$	—		$	218	$	204	$	544		$	546
O&R
Electric	$	128		$	149		$	—		$	—		$	9	$	9	$	8		$	10
Gas		82			92			—			—			4		3		30			28
Total O&R	$	210		$	241		$	—		$	—		$	13	$	12	$	38		$	38
Competitive energy businesses	$	310		$	408		$	2		$	3		$	2	$	2	$	(20	)	$	44
Other*		(3	)		(9	)		(2	)		(3	)		—		—		(1	)		(2	)
Total Con Edison	$	3,078		$	3,349		$	—		$	—		$	233	$	218	$	561		$	626

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

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Other Material Contingencies (Tables)

3 Months Ended

Mar. 31, 2012

Other Material Contingencies [Abstract]

Total Guarantees

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	637	$	4	$	66	$	707
Intra-company guarantees		15		—		1		16
Other guarantees		33		4		—		37
TOTAL	$	685	$	8	$	67	$	760

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Derivative Instruments And Hedging Activities (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Schedule of Investments [Line Items]
Energy supply and hedging activities credit exposure total	$ 121
Makeup of net credit exposure, with investment-grade counterparties	46
Makeup of net credit exposure with commodity exchange brokers	37
Makeup of net credit exposure independent system operators	36
Makeup of net credit exposure non-rated counterparties	2
Number of contracts, considered derivatives	1,392
Unrealized gain (loss) on derivatives	(90)	[1]	(17)	[1]
Interest Rate Swaps [Member]
Schedule of Investments [Line Items]
Unrealized gain (loss) on derivatives	$ (8)
Derivative, fixed interest rate	6.09%

[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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Derivative Instruments And Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2012

Derivative Instruments And Hedging Activities [Abstract]

Energy Price Hedging Fair Values

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Fair value of net derivative assets/(liabilities) – gross	$	(331	)	$	(249	)	$	(181	)	$	(144	)
Impact of netting of cash collateral		156			110			64			46
Fair value of net derivative assets/(liabilities) – net	$	(175	)	$	(139	)	$	(117	)	$	(98	)

Fair Values Of The Companies' Commodity Derivatives

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivatives Asset
Current	Other current assets	$	179		$	20
Long-term	Other deferred charges and non-current assets		25			6
Total derivatives asset		$	204		$	26
Impact of netting			(134	)		—
Net derivatives asset		$	70		$	26
Derivatives Liability
Current	Fair value of derivative liabilities	$	433		$	149
Long-term	Fair value of derivative liabilities		102			58
Total derivatives liability		$	535		$	207
Impact of netting			(290	)		(64	)
Net derivatives liability		$	245		$	143

(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.

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivatives Asset
Current	Other current assets	$	139		$	16
Long-term	Other deferred charges and non-current assets		26			14
Total derivatives asset		$	165		$	30
Impact of netting			(95	)		(6	)
Net derivatives asset		$	70		$	24
Derivatives Liability
Current	Fair value of derivative liabilities	$	331		$	127
Long-term	Fair value of derivative liabilities		83			48
Total derivatives liability		$	414		$	175
Impact of netting			(205	)		(53	)
Net derivatives liability		$	209		$	122

(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 March 31, 2012
(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	$	1		$	1
Total deferred gains		$	1		$	1
Current	Deferred derivative losses	$	(28	)	$	(19	)
Current	Recoverable energy costs		(74	)		(56	)
Long-term	Regulatory assets		(18	)		(17	)
Total deferred losses		$	(120	)	$	(92	)
Net deferred losses		$	(119	)	$	(91	)
	Income Statement Location
Pre-tax loss recognized in income
	Purchased power expense	$	(86	)(b)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		(3	)(b)		—
Total pre-tax loss recognized in income		$	(90	)	$	—

(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 March 31, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax loss of $(4) million and $(27) million, respectively.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended March 31, 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	$	6		$	5
Long-term	Regulatory liabilities		3			3
Total deferred gains		$	9		$	8
Current	Deferred derivative losses	$	44		$	35
Current	Recoverable energy costs		(49	)		(42	)
Long-term	Regulatory assets		17			11
Total deferred losses		$	12		$	4
Net deferred losses		$	21		$	12
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(21	)(b)	$	—
	Gas purchased for resale		(6	)		—
	Non-utility revenue		10	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(17	)	$	—

(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 March 31, 2011, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $50 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		754		16,197,114		59		7,639		579		91,840,940		1,392
CECONY		141		3,771,625		—		—		441		84,940,000		582

(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	$	245		$	143
Collateral posted	$	64		$	51
Additional collateral (b) (downgrade one level from current ratings (c))	$	35		$	18
Additional collateral (b) (downgrade to below investment grade from current ratings (c))	$	225	(d)	$	106	(d)

(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 March 31, 2012, would have amounted to an estimated $39 million for Con Edison, including $9 million for CECONY. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) 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.

(d) Derivative instruments that are net assets have been excluded from the table. At March 31, 2012, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of not more than $23 million.

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2012

Fair Value Measurements [Abstract]

Assets And Liabilities Measured At Fair Value On A Recurring Basis

Assets and liabilities measured at fair value on a recurring basis as of March 31, 2012 are summarized below.

	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	$	—	$	86	$	4	$	103		$	13		$	(122	)	$	9		$	69		$	26
Other assets (3)		83		83		—		—		105			95			—			—			188			178
Transfer in (5) (6)		—		—		105		95		—			—			—			—			105			95
Transfer out (5) (6)		—		—		—		—		(105	)		(95	)		—			—			(105	)		(95	)
Other assets (3)	$	83	$	83	$	105	$	95	$	—		$	—		$	—		$	—		$	188		$	178
Total	$	85	$	83	$	191	$	99	$	103		$	13		$	(122	)	$	9		$	257		$	204
Derivative liabilities:
Commodity (1)	$	10	$	2	$	316	$	170	$	196		$	26		$	(278	)	$	(55	)	$	244		$	143
Interest rate contract (2)		—		—		—		—		8			—			—			—			8			—
Transfer in (5) (6)		—		—		8		—		—			—			—			—			8			—
Transfer out (5) (6)		—		—		—		—		(8	)		—			—			—			(8	)		—
Interest rate contract (2)	$	—	$	—	$	8	$	—	$	—		$	—		$	—		$	—		$	8		$	—
Total	$	10	$	2	$	324	$	170	$	196		$	26		$	(278	)	$	(55	)	$	252		$	143

(1) A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

(2) See Note J.

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

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

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2011 are summarized below.

	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)	$	3	$	—	$	64		$	8		$	87		$	11		$	(84	)	$	5		$	70		$	24
Other assets (3)		76		76		—			—			99			90			—			—			175			166
Total	$	79	$	76	$	64		$	8		$	186		$	101		$	(84	)	$	5		$	245		$	190
Derivative liabilities:
Commodity	$	12	$	4	$	222		$	122		$	169		$	37		$	(194	)	$	(41	)	$	209		$	122
Transfer in (5) (6) (7)		—		—		26			25			6			6			—			—			32			31
Transfer out (5) (6) (7)		—		—		(6	)		(6	)		(26	)		(25	)		—			—			(32	)		(31	)
Commodity (1)	$	12	$	4	$	242		$	141		$	149		$	18		$	(194	)	$	(41	)	$	209		$	122
Interest rate contract (2)		—		—		—			—			8			—			—			—			8			—
Total	$	12	$	4	$	242		$	141		$	157		$	18		$	(194	)	$	(41	)	$	217		$	122

(1) A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

(2) See Note J.

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

(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, 2010 to less than one year as of December 31, 2011.

Schedule Of Commodity Derivatives

(Millions of Dollars)	Fair Value of Level 3 at 3/31/2012			Valuation Techniques	Unobservable Inputs
Con Edison
Commodity	$	(93	)	Market approach (1)	Discount for inactive markets and/or illiquid locations (2)
CECONY
Commodity	$	(13	)	Market approach (1)	Discount for inactive markets and/or illiquid locations (2)

(1) The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets and liabilities. The commodity derivatives are valued using quoted prices or internally developed models with observable inputs, adjusted for certain contracts that are traded in inactive markets and/or at illiquid locations. The unobservable inputs used in the Companies' models do not have a significant impact on the valuation.

(2) Significant increases or decreases in any of these inputs in isolation would have a limited impact on fair value measurement. Generally, a change in the fair value measurement is linearly based on changes in these inputs.

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

	For the Three Months Ended March 31, 2012
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2012			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of March 31, 2012
Con Edison
Derivatives:
Commodity	$	(62	)	$	(58	)	$	(17	)	$	6	$	—	$	—	$	38	$	—		$	(93	)
Interest rate contract		(8	)		(1	)		—			—		—		—		1		8			—
Other assets (1)		99			3			3			—		—		—		—		(105	)		—
Total	$	29		$	(56	)	$	(14	)	$	6	$	—	$	—	$	39	$	(97	)	$	(93	)
CECONY
Derivatives:
Commodity	$	(7	)	$	(5	)	$	(7	)	$	6	$	—	$	—	$	—	$	—		$	(13	)
Other assets (1)		90			3			2			—		—		—		—		(95	)		—
Total	$	83		$	(2	)	$	(5	)	$	6	$	—	$	—	$	—	$	(95	)	$	(13	)

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

	For the Three Months Ended March 31, 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 March 31, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	9		$	40	$	10	$	—	$	—	$	3		$	(5	)	$	(31	)
Interest rate contract		(10	)		(1	)		—		—		—		—		1			—			(10	)
Other assets (1)		101			2			2		—		—		—		—			—			105
Total	$	3		$	10		$	42	$	10	$	—	$	—	$	4		$	(5	)	$	64
CECONY
Derivatives:
Commodity	$	(26	)	$	(1	)	$	27	$	10	$	—	$	—	$	(3	)	$	(5	)	$	2
Other assets (1)		92			2			1		—		—		—		—			—			95
Total	$	66		$	1		$	28	$	10	$	—	$	—	$	(3	)	$	(5	)	$	97

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

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Consolidated Statement Of Common Shareholders' Equity (USD $) In Millions, except Share data	Common Stock [Member] CECONY [Member]	Common Stock [Member]	Additional Paid-In Capital [Member] CECONY [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member] CECONY [Member]	Retained Earnings [Member]	Treasury Stock [Member]	Repurchased Con Edison Stock [Member] CECONY [Member]	Capital Stock Expense [Member] CECONY [Member]	Capital Stock Expense [Member]	Accumulated Other Comprehensive Income/(Loss) [Member] CECONY [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	CECONY [Member]	Total
BALANCE at Dec. 31, 2010	$ 589	$ 31	$ 4,234	$ 4,915	$ 6,132	$ 7,220	$ (1,001)	$ (962)	$ (64)	$ (64)	$ (6)	$ (40)	$ 9,923	$ 11,061
BALANCE (in shares) at Dec. 31, 2010	235,488,094	291,616,334					23,210,700
Net income					271								271	314
Net income for common stock						311							268	311
Common stock dividends					(170)	(175)							(170)	(175)
Cumulative preferred dividends					(3)								(3)	(3)
Issuance of common shares - dividend reinvestment and employee stock plans		1		30										31
Issuance of common shares - dividend reinvestment and employee stock plans (in shares)		656,049
Other comprehensive income												3		3
BALANCE at Mar. 31, 2011	589	32	4,234	4,945	6,230	7,356	(1,001)	(962)	(64)	(64)	(6)	(37)	10,021	11,231
BALANCE (in shares) at Mar. 31, 2011	235,488,094	292,272,383					23,210,700
BALANCE at Dec. 31, 2011	589	32	4,234	4,991	6,429	7,568	(1,033)	(962)	(64)	(64)	(8)	(58)	10,218	11,436
BALANCE (in shares) at Dec. 31, 2011	235,488,094	292,888,521					23,194,075
Net income					276								276	280
Net income for common stock						277							273	277
Common stock dividends					(171)	(177)							(171)	(177)
Cumulative preferred dividends					(3)								(3)	(3)
Issuance of common shares - dividend reinvestment and employee stock plans							(2)							(2)
Issuance of common shares - dividend reinvestment and employee stock plans (in shares)		(7,225)					7,225
Preferred stock redemption									4	4			4	4
Other comprehensive income												7		7
BALANCE at Mar. 31, 2012	$ 589	$ 32	$ 4,234	$ 4,991	$ 6,531	$ 7,668	$ (1,035)	$ (962)	$ (60)	$ (60)	$ (8)	$ (51)	$ 10,324	$ 11,545
BALANCE (in shares) at Mar. 31, 2012	235,488,094	292,881,296					23,201,300

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Summary Of Significant Accounting Policies (Earnings Per Common Share) (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Summary Of Significant Accounting Policies [Abstract]
Net income for common stock	$ 277	$ 311
Weighted average common shares outstanding - Basic	292.9	292.0
Add: Incremental shares attributable to effect of potentially dilutive securities	1.6	1.6
Adjusted weighted average common shares outstanding - Diluted	294.5	293.6
Net income for common stock per common share - basic	$ 0.95	$ 1.07
Net income for common stock per common share - diluted	$ 0.94	$ 1.06

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Environmental Matters (Accrued Liability For Asbestos Suits And Workers' Compensation Proceedings) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Site Contingency [Line Items]
Regulatory assets	$ 9,468	$ 9,501
Asbestos Suits [Member]
Site Contingency [Line Items]
Accrued liability	10	10
Regulatory assets	10	10
Workers' Compensation [Member]
Site Contingency [Line Items]
Accrued liability	96	98
Regulatory assets	$ 22	$ 23

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, unless otherwise specified	3 Months Ended
	Mar. 31, 2012		Mar. 31, 2011
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ 29		$ 3
Included in Earnings	(56)		10
Included in Regulatory Assets and Liabilities	(14)		42
Purchases	6		10
Issuances
Sales
Settlements	39		4
Transfers In/Out of Level 3	(97)		(5)
Ending Balance	(93)		64
Commodity [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	(62)		(88)
Included in Earnings	(58)		9
Included in Regulatory Assets and Liabilities	(17)		40
Purchases	6		10
Issuances
Sales
Settlements	38		3
Transfers In/Out of Level 3			(5)
Ending Balance	(93)		(31)
Interest Rate Contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	(8)		(10)
Included in Earnings	(1)		(1)
Issuances
Sales
Settlements	1		1
Transfers In/Out of Level 3	8
Ending Balance			(10)
Other Assets [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	99	[1]	101	[1]
Included in Earnings	3	[1]	2	[1]
Included in Regulatory Assets and Liabilities	3	[1]	2	[1]
Issuances				[1]
Sales				[1]
Transfers In/Out of Level 3	(105)	[1]
Ending Balance			$ 105	[1]

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

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Consolidated Income Statement (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
OPERATING REVENUES
Electric	$ 1,862	$ 1,869
Gas	645	755
Steam	263	325
Non-utility	308	400
TOTAL OPERATING REVENUES	3,078	3,349
OPERATING EXPENSES
Purchased power	781	865
Fuel	108	176
Gas purchased for resale	196	308
Operations and maintenance	749	698
Depreciation and amortization	233	218
Taxes, other than income taxes	450	458
TOTAL OPERATING EXPENSES	2,517	2,723
OPERATING INCOME	561	626
OTHER INCOME (DEDUCTIONS)
Investment and other income	7	9
Allowance for equity funds used during construction		4
Other deductions	(4)	(4)
TOTAL OTHER INCOME (DEDUCTIONS)	3	9
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	564	635
INTEREST EXPENSE
Interest on long-term debt	145	147
Other interest	5	7
Allowance for borrowed funds used during construction		(2)
NET INTEREST EXPENSE	150	152
INCOME BEFORE INCOME TAX EXPENSE	414	483
INCOME TAX EXPENSE	134	169
NET INCOME	280	314
Preferred stock dividend requirements of subsidiary	(3)	(3)
NET INCOME FOR COMMON STOCK	277	311
Net income for common stock per common share - basic	$ 0.95	$ 1.07
Net income for common stock per common share - diluted	$ 0.94	$ 1.06
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK	$ 0.605	$ 0.600
AVERAGE NUMBER OF SHARES OUTSTANDING - BASIC (IN MILLIONS)	292.9	292.0
AVERAGE NUMBER OF SHARES OUTSTANDING - DILUTED (IN MILLIONS)	294.5	293.6
CECONY [Member]
OPERATING REVENUES
Electric	1,735	1,721
Gas	563	663
Steam	263	325
TOTAL OPERATING REVENUES	2,561	2,709
OPERATING EXPENSES
Purchased power	447	483
Fuel	108	176
Gas purchased for resale	169	263
Operations and maintenance	645	597
Depreciation and amortization	218	204
Taxes, other than income taxes	430	440
TOTAL OPERATING EXPENSES	2,017	2,163
OPERATING INCOME	544	546
OTHER INCOME (DEDUCTIONS)
Investment and other income	5	5
Allowance for equity funds used during construction		3
Other deductions	(3)	(3)
TOTAL OTHER INCOME (DEDUCTIONS)	2	5
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	546	551
INTEREST EXPENSE
Interest on long-term debt	131	132
Other interest	5	5
Allowance for borrowed funds used during construction		(2)
NET INTEREST EXPENSE	136	135
INCOME BEFORE INCOME TAX EXPENSE	410	416
INCOME TAX EXPENSE	134	145
NET INCOME	276	271
Preferred stock dividend requirements of subsidiary	(3)	(3)
NET INCOME FOR COMMON STOCK	$ 273	$ 268

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Derivative Instruments And Hedging Activities (Energy Price Hedging Fair Values) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Derivative Instruments And Hedging Activities [Abstract]
Fair value of net derivative assets/(liabilities) - gross	$ (331)	$ (249)
Impact of netting of cash collateral	156	110
Fair value of net derivative assets/(liabilities) - net	$ (175)	$ (139)

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Consolidated Balance Sheet (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
CURRENT ASSETS
Cash and temporary cash investments	$ 769	$ 648
Accounts receivable - customers	1,069	1,123
Accrued unbilled revenue	379	474
Other receivables	249	303
Fuel oil, gas in storage, materials and supplies, at average cost	325	356
Prepayments	431	145
Deferred tax assets - current	285	266
Regulatory assets	192	164
Other current assets	205	159
TOTAL CURRENT ASSETS	3,904	3,638
INVESTMENTS	440	455
UTILITY PLANT, AT ORIGINAL COST
General	2,093	1,960
TOTAL	30,449	29,775
Less: Accumulated depreciation	6,153	6,051
Net	24,296	23,724
Construction work in progress	920	1,241
NET UTILITY PLANT	25,216	24,965
NON-UTILITY PLANT
Non-utility property	98	89
Construction work in progress	39	39
NET PLANT	25,353	25,093
OTHER NONCURRENT ASSETS
Goodwill	429	429
Intangible assets, less accumulated amortization of $3 in 2012 and 2011	3	3
Regulatory assets	9,276	9,337
Other deferred charges and noncurrent assets	296	259
TOTAL OTHER NONCURRENT ASSETS	10,004	10,028
TOTAL ASSETS	39,701	39,214
CURRENT LIABILITIES
Long-term debt due within one year	1,030	530
Accounts payable	844	955
Customer deposits	306	303
Accrued taxes	229	188
Accrued interest	212	160
Accrued wages	91	91
Fair value of derivative liabilities	198	169
Regulatory liabilities	286	118
Preferred stock redemption	239
Other current liabilities	405	473
TOTAL CURRENT LIABILITIES	3,840	2,987
NONCURRENT LIABILITIES
Obligations under capital leases	2	2
Provision for injuries and damages	158	181
Pensions and retiree benefits	4,605	4,835
Superfund and other environmental costs	537	489
Asset retirement obligations	147	145
Fair value of derivative liabilities	54	48
Other noncurrent liabilities	131	131
TOTAL NONCURRENT LIABILITIES	5,634	5,831
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	7,712	7,563
Regulatory liabilities	846	977
Other deferred credits	83	64
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	8,641	8,604
LONG-TERM DEBT	10,041	10,143
SHAREHOLDERS' EQUITY
Common shareholders' equity (See Statement of Common Shareholders' Equity)	11,545	11,436
Preferred stock of subsidiary		213
TOTAL SHAREHOLDERS' EQUITY	11,545	11,649
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	39,701	39,214
CECONY [Member]
CURRENT ASSETS
Cash and temporary cash investments	475	372
Accounts receivable - customers	934	977
Accrued unbilled revenue	285	366
Other receivables	110	102
Accounts receivable from affiliated companies	36	54
Fuel oil, gas in storage, materials and supplies, at average cost	286	308
Prepayments	372	85
Deferred tax assets - current	170	157
Regulatory assets	159	140
Other current assets	97	100
TOTAL CURRENT ASSETS	2,924	2,661
INVESTMENTS	188	177
UTILITY PLANT, AT ORIGINAL COST
General	1,917	1,785
TOTAL	28,501	27,854
Less: Accumulated depreciation	5,616	5,523
Net	22,885	22,331
Construction work in progress	853	1,165
NET UTILITY PLANT	23,738	23,496
NON-UTILITY PLANT
Non-utility property	6	6
NET PLANT	23,744	23,502
OTHER NONCURRENT ASSETS
Regulatory assets	8,645	8,661
Other deferred charges and noncurrent assets	254	217
TOTAL OTHER NONCURRENT ASSETS	8,899	8,878
TOTAL ASSETS	35,755	35,218
CURRENT LIABILITIES
Long-term debt due within one year	1,024	525
Accounts payable	690	774
Accounts payable to affiliated companies	17	16
Customer deposits	293	290
Accrued taxes	17	32
Accrued taxes to affiliated companies	198	126
Accrued interest	175	133
Accrued wages	82	81
Fair value of derivative liabilities	112	98
Regulatory liabilities	242	79
Preferred stock redemption	239
Other current liabilities	338	396
TOTAL CURRENT LIABILITIES	3,427	2,550
NONCURRENT LIABILITIES
Obligations under capital leases	2	2
Provision for injuries and damages	151	173
Pensions and retiree benefits	4,142	4,337
Superfund and other environmental costs	421	373
Asset retirement obligations	147	145
Fair value of derivative liabilities	31	24
Other noncurrent liabilities	121	120
TOTAL NONCURRENT LIABILITIES	5,015	5,174
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	7,059	6,921
Regulatory liabilities	730	861
Other deferred credits	81	61
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	7,870	7,843
LONG-TERM DEBT	9,119	9,220
SHAREHOLDERS' EQUITY
Common shareholders' equity (See Statement of Common Shareholders' Equity)	10,324	10,218
Preferred stock of subsidiary		213
TOTAL SHAREHOLDERS' EQUITY	10,324	10,431
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	35,755	35,218
Electric Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	21,520	21,105
Electric Transmission [Member] | CECONY [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	20,284	19,886
Gas Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	4,821	4,727
Gas Transmission [Member] | CECONY [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	4,285	4,200
Steam Plant [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,015	1,983
Steam Plant [Member] | CECONY [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,015	$ 1,983

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Short-Term Borrowing (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012
Short-Term Borrowing [Abstract]
Letters of credit outstanding under the Credit Agreement	$ 183

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Summary Of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2012

Summary Of Significant Accounting Policies [Abstract]

Earnings Per Common Share

(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011
Net income for common stock	$	277	$	311
Weighted average common shares outstanding – Basic		292.9		292.0
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		293.6
Net income for common stock per common share – basic	$	0.95	$	1.07
Net income for common stock per common share – diluted	$	0.94	$	1.06

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Pension Benefits (Companies' Net Periodic Benefit Costs) (Details) (Pension Benefits [Member], USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	$ 59	$ 47
Interest cost on projected benefit obligation	137	140
Expected return on plan assets	(176)	(183)
Amortization of net actuarial loss	177	132
Amortization of prior service costs	2	2
NET PERIODIC BENEFIT COST	199	138
Cost capitalized	(64)	(48)
Cost deferred	(37)	(51)
Cost charged to operating expenses	98	39
Estimated future employer contributions	775
Expect to fund	$ 12

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Capitalization (Tables)

3 Months Ended

Mar. 31, 2012

Capitalization [Abstract]

Carrying Amounts And Fair Values Of Long-term Debt

(millions of dollars)	March 31, 2012				December 31, 2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison	$	11,071	$	12,892	$	10,673	$	12,744
CECONY	$	10,143	$	11,757	$	9,745	$	11,593

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Consolidated Balance Sheet (Parenthetical) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Accounts receivable - customers, allowance for uncollectible accounts	$ 87	$ 87
Other receivables, allowance for uncollectible accounts	10	10
Non-utility property, accumulated depreciation	61	59
Intangible assets, accumulated amortization	3	3
CECONY [Member]
Accounts receivable - customers, allowance for uncollectible accounts	79	79
Other receivables, allowance for uncollectible accounts	9	9
Non-utility property, accumulated depreciation	$ 24	$ 24

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Consolidated Statement Of Comprehensive Income (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
NET INCOME	$ 280	$ 314
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension plan liability adjustments	7	3
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	7	3
COMPREHENSIVE INCOME	287	317
Preferred stock dividend requirements of subsidiary	(3)	(3)
COMPREHENSIVE INCOME FOR COMMON STOCK	284	314
CECONY [Member]
NET INCOME	276	271
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension plan liability adjustments
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
COMPREHENSIVE INCOME	276	271
Preferred stock dividend requirements of subsidiary	$ (3)	$ (3)

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Other Material Contingencies

3 Months Ended

Mar. 31, 2012

Other Material Contingencies

Note H — Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately 93 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 been convicted of 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 2011 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 $(65) million at March 31, 2012 and $(55) million at December 31, 2011 and is comprised of a $228 million gross investment less $293 million of deferred tax liabilities at March 31, 2012 and $234 million gross investment less $289 million of deferred tax liabilities at December 31, 2011.

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 appealed the decision in December 2011.

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 March 31, 2012, in the aggregate, was $240 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 $114 million net of tax at March 31, 2012.

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 $760 million at March 31, 2012 and December 31, 2011, respectively.

A summary, by type and term, of Con Edison's total guarantees at March 31, 2012 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	637	$	4	$	66	$	707
Intra-company guarantees		15		—		1		16
Other guarantees		33		4		—		37
TOTAL	$	685	$	8	$	67	$	760

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 and Con Edison Development also guarantee the following:

• $7 million relates to guarantees issued by Con Edison to CECONY covering a former Con Edison subsidiary's lease payment 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;

• $5 million for guarantees provided by Con Edison Development to Travelers Insurance Company for indemnity agreements for surety bonds in connection with the construction and operation of solar facilities performed by its subsidiaries; 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 March 31, 2012.

CECONY [Member]

Other Material Contingencies

Note H — Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately 93 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 been convicted of 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 2011 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 $(65) million at March 31, 2012 and $(55) million at December 31, 2011 and is comprised of a $228 million gross investment less $293 million of deferred tax liabilities at March 31, 2012 and $234 million gross investment less $289 million of deferred tax liabilities at December 31, 2011.

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 appealed the decision in December 2011.

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 March 31, 2012, in the aggregate, was $240 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 $114 million net of tax at March 31, 2012.

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 $760 million at March 31, 2012 and December 31, 2011, respectively.

A summary, by type and term, of Con Edison's total guarantees at March 31, 2012 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	637	$	4	$	66	$	707
Intra-company guarantees		15		—		1		16
Other guarantees		33		4		—		37
TOTAL	$	685	$	8	$	67	$	760

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 and Con Edison Development also guarantee the following:

• $7 million relates to guarantees issued by Con Edison to CECONY covering a former Con Edison subsidiary's lease payment 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;

• $5 million for guarantees provided by Con Edison Development to Travelers Insurance Company for indemnity agreements for surety bonds in connection with the construction and operation of solar facilities performed by its subsidiaries; 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 March 31, 2012.

XML

Document And Entity Information	3 Months Ended
	Mar. 31, 2012	Apr. 27, 2012
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1
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		292,904,261
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

Financial Information By Business Segment

3 Months Ended

Mar. 31, 2012

Financial Information By Business Segment

Note I — Financial Information by Business Segment

The financial data for the business segments are as follows:

	For the Three Months Ended March 31,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012			2011			2012			2011			2012		2011		2012			2011
CECONY
Electric	$	1,735		$	1,721		$	3		$	3		$	173	$	161	$	224		$	217
Gas		563			663			1			1			29		27		221			204
Steam		263			325			19			20			16		16		99			125
Consolidation adjustments		—			—			(23	)		(24	)		—		—		—			—
Total CECONY	$	2,561		$	2,709		$	—		$	—		$	218	$	204	$	544		$	546
O&R
Electric	$	128		$	149		$	—		$	—		$	9	$	9	$	8		$	10
Gas		82			92			—			—			4		3		30			28
Total O&R	$	210		$	241		$	—		$	—		$	13	$	12	$	38		$	38
Competitive energy businesses	$	310		$	408		$	2		$	3		$	2	$	2	$	(20	)	$	44
Other*		(3	)		(9	)		(2	)		(3	)		—		—		(1	)		(2	)
Total Con Edison	$	3,078		$	3,349		$	—		$	—		$	233	$	218	$	561		$	626

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

CECONY [Member]

Financial Information By Business Segment

Note I — Financial Information by Business Segment

The financial data for the business segments are as follows:

	For the Three Months Ended March 31,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012			2011			2012			2011			2012		2011		2012			2011
CECONY
Electric	$	1,735		$	1,721		$	3		$	3		$	173	$	161	$	224		$	217
Gas		563			663			1			1			29		27		221			204
Steam		263			325			19			20			16		16		99			125
Consolidation adjustments		—			—			(23	)		(24	)		—		—		—			—
Total CECONY	$	2,561		$	2,709		$	—		$	—		$	218	$	204	$	544		$	546
O&R
Electric	$	128		$	149		$	—		$	—		$	9	$	9	$	8		$	10
Gas		82			92			—			—			4		3		30			28
Total O&R	$	210		$	241		$	—		$	—		$	13	$	12	$	38		$	38
Competitive energy businesses	$	310		$	408		$	2		$	3		$	2	$	2	$	(20	)	$	44
Other*		(3	)		(9	)		(2	)		(3	)		—		—		(1	)		(2	)
Total Con Edison	$	3,078		$	3,349		$	—		$	—		$	233	$	218	$	561		$	626

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

XML

Consolidated Statement Of Comprehensive Income (Parenthetical) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Pension plan liability adjustments, taxes	$ 5	$ 2
CECONY [Member]
Pension plan liability adjustments, taxes

XML

Capitalization

3 Months Ended

Mar. 31, 2012

Capitalization

Note C — Capitalization

In March 2012, CECONY issued $400 million of 4.20 percent 30-year debentures, $239 million of the net proceeds from the sale of which were used to redeem on May 1, 2012 all outstanding shares of its $5 Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value).

The carrying amounts and fair values of long-term debt are:

(millions of dollars)	March 31, 2012				December 31, 2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison	$	11,071	$	12,892	$	10,673	$	12,744
CECONY	$	10,143	$	11,757	$	9,745	$	11,593

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,256 million and $636 million of the fair value of long-term debt at March 31, 2012 are classified as Level 2 and Level 3, respectively. For CECONY, $11,121 million and $636 million of the fair value of long-term debt at March 31, 2012 are classified as Level 2 and Level 3, respectively (see Note K).

CECONY [Member]

Capitalization

Note C — Capitalization

In March 2012, CECONY issued $400 million of 4.20 percent 30-year debentures, $239 million of the net proceeds from the sale of which were used to redeem on May 1, 2012 all outstanding shares of its $5 Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value).

The carrying amounts and fair values of long-term debt are:

(millions of dollars)	March 31, 2012				December 31, 2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison	$	11,071	$	12,892	$	10,673	$	12,744
CECONY	$	10,143	$	11,757	$	9,745	$	11,593

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,256 million and $636 million of the fair value of long-term debt at March 31, 2012 are classified as Level 2 and Level 3, respectively. For CECONY, $11,121 million and $636 million of the fair value of long-term debt at March 31, 2012 are classified as Level 2 and Level 3, respectively (see Note K).

XML

Regulatory Matters

3 Months Ended

Mar. 31, 2012

Regulatory Matters

Note B — Regulatory Matters

Rate Agreements

CECONY — Electric

In March 2012, the NYSPSC issued an order requiring that the $134 million surcharge that was to have been collected from customers during the rate year ending March 2013 instead be offset using certain CECONY regulatory liabilities that would have otherwise been refundable to or applied for the benefit of customers after the rate year.

O&R — Electric

On February 24, 2012, O&R, the staff of the NYSPSC and the Utility Intervention Unit of New York State's Division of Consumer Protection entered into a Joint Proposal with respect to the Company's rates for electric delivery service rendered in New York. The Joint Proposal, which is subject to NYSPSC approval, covers the three-year period from July 2012 through June 2015. The Joint Proposal provides for electric base rate increases of $19.4 million, $8.8 million and $15.2 million, effective July 2012, 2013 and 2014, respectively, which can be implemented, at the NYSPSC's option, with increases of $15.2 million effective July 2012 and 2013 and an increase of $13.1 million, together with a surcharge of $2.1 million, effective July 2014. The Joint Proposal reflects the following major items:

• a weighted average cost of capital of 7.61 percent, 7.65 percent and 7.48 percent for the rate years ending June 30, 2013, 2014 and 2015, respectively, reflecting:

• a return on common equity of 9.4 percent, 9.5 percent and 9.6 percent for the rate years ending June 30, 2013, 2014 and 2015, respectively;

• cost of long-term debt of 6.07 percent for each of the rate years ending June 30, 2013 and 2014 and 5.64 percent for the rate year ending June 30 2015;

• common equity ratio of 48 percent for each of the rate years ending June 30, 2013, 2014 and 2015; and

• average rate base of $671 million, $708 million and $759 million for the rate years ending June 30, 2013, 2014 and 2015, respectively;

• sharing with electric customers of any actual earnings, excluding the effects of any penalties and certain other items, above specified percentage returns on common equity (based on the actual average common equity ratio, subject to a 50 percent maximum):

• the company will allocate to customers the revenue requirement equivalent of 50 percent, 75 percent and 90 percent of any such earnings for each rate year in excess of 80 basis points, 180 basis points and 280 basis points, respectively, above the return on common equity for that rate year indicated above; and

• the earnings sharing allocation between the company and customers will be done on a cumulative basis at the end of rate year three;

• continuation of a revenue decoupling mechanism;

• continuation of a provision which defers as a regulatory liability for the benefit of customers or, subject to certain limitations, a regulatory asset for recovery from customers, as the case may be, the revenue requirement impact of the amount by which actual average net utility plant for each rate year is different than the average net utility plant reflected in rates ($678 million, $704 million and $753 million for the rate years ending June 30, 2013, 2014 and 2015, respectively);

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

• 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;

• provisions under which property taxes are reconciled to amounts reflected in rates; and

• 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.

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 H). 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 March 31, 2012, the company had collected an estimated $887 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 March 31, 2012, the company had an $8 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 G.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at March 31, 2012 and December 31, 2011 were comprised of the following items:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Regulatory assets
Unrecognized pension and other postretirement costs	$	5,594	$	5,852	$	5,337	$	5,554
Future income tax		1,840		1,798		1,764		1,724
Environmental remediation costs		729		681		613		564
Pension and other post retirement benefits deferrals		219		198		185		157
Revenue taxes		167		163		161		158
Surcharge for New York State assessment		143		90		133		82
Deferred storm costs		125		128		79		80
Net electric deferrals		116		121		116		121
Deferred derivative losses – long-term		78		60		61		44
O&R transition bond charges		43		44		—		—
Preferred stock redemption		30		—		30		—
Workers' compensation		22		23		21		23
Property tax reconciliation		13		13		—		—
Recoverable energy costs – long-term		—		14		—		14
Other		157		152		145		140
Regulatory assets – long-term		9,276		9,337		8,645		8,661
Deferred derivative losses – current		192		164		159		140
Regulatory assets – current		192		164		159		140
Total Regulatory Assets	$	9,468	$	9,501	$	8,804	$	8,801
Regulatory liabilities
Allowance for cost of removal less salvage	$	457	$	448	$	379	$	372
Property tax reconciliation		68		35		68		35
World Trade Center settlement proceeds		62		62		62		62
Net unbilled revenue deferrals		51		104		51		104
Long-term interest rate reconciliation		42		30		42		30
Carrying charges on transmission and distribution net plant		41		38		18		14
Gas line losses		17		21		17		21
Expenditure prudence proceeding		8		11		8		11
Energy efficiency programs		6		22		6		20
Other		94		206		79		192
Regulatory liabilities – long-term		846		977		730		861
Electric surcharge offset		134		—		134		—
Refundable energy costs – current		99		51		55		12
Revenue decoupling mechanism		51		66		51		66
Deferred derivative gains – current		2		1		2		1
Regulatory liabilities – current		286		118		242		79
Total Regulatory Liabilities	$	1,132	$	1,095	$	972	$	940

CECONY [Member]

Regulatory Matters

Note B — Regulatory Matters

Rate Agreements

CECONY — Electric

In March 2012, the NYSPSC issued an order requiring that the $134 million surcharge that was to have been collected from customers during the rate year ending March 2013 instead be offset using certain CECONY regulatory liabilities that would have otherwise been refundable to or applied for the benefit of customers after the rate year.

O&R — Electric

On February 24, 2012, O&R, the staff of the NYSPSC and the Utility Intervention Unit of New York State's Division of Consumer Protection entered into a Joint Proposal with respect to the Company's rates for electric delivery service rendered in New York. The Joint Proposal, which is subject to NYSPSC approval, covers the three-year period from July 2012 through June 2015. The Joint Proposal provides for electric base rate increases of $19.4 million, $8.8 million and $15.2 million, effective July 2012, 2013 and 2014, respectively, which can be implemented, at the NYSPSC's option, with increases of $15.2 million effective July 2012 and 2013 and an increase of $13.1 million, together with a surcharge of $2.1 million, effective July 2014. The Joint Proposal reflects the following major items:

• a weighted average cost of capital of 7.61 percent, 7.65 percent and 7.48 percent for the rate years ending June 30, 2013, 2014 and 2015, respectively, reflecting:

• a return on common equity of 9.4 percent, 9.5 percent and 9.6 percent for the rate years ending June 30, 2013, 2014 and 2015, respectively;

• cost of long-term debt of 6.07 percent for each of the rate years ending June 30, 2013 and 2014 and 5.64 percent for the rate year ending June 30 2015;

• common equity ratio of 48 percent for each of the rate years ending June 30, 2013, 2014 and 2015; and

• average rate base of $671 million, $708 million and $759 million for the rate years ending June 30, 2013, 2014 and 2015, respectively;

• sharing with electric customers of any actual earnings, excluding the effects of any penalties and certain other items, above specified percentage returns on common equity (based on the actual average common equity ratio, subject to a 50 percent maximum):

• the company will allocate to customers the revenue requirement equivalent of 50 percent, 75 percent and 90 percent of any such earnings for each rate year in excess of 80 basis points, 180 basis points and 280 basis points, respectively, above the return on common equity for that rate year indicated above; and

• the earnings sharing allocation between the company and customers will be done on a cumulative basis at the end of rate year three;

• continuation of a revenue decoupling mechanism;

• continuation of a provision which defers as a regulatory liability for the benefit of customers or, subject to certain limitations, a regulatory asset for recovery from customers, as the case may be, the revenue requirement impact of the amount by which actual average net utility plant for each rate year is different than the average net utility plant reflected in rates ($678 million, $704 million and $753 million for the rate years ending June 30, 2013, 2014 and 2015, respectively);

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

• 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;

• provisions under which property taxes are reconciled to amounts reflected in rates; and

• 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.

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 H). 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 March 31, 2012, the company had collected an estimated $887 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 March 31, 2012, the company had an $8 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 G.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at March 31, 2012 and December 31, 2011 were comprised of the following items:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Regulatory assets
Unrecognized pension and other postretirement costs	$	5,594	$	5,852	$	5,337	$	5,554
Future income tax		1,840		1,798		1,764		1,724
Environmental remediation costs		729		681		613		564
Pension and other post retirement benefits deferrals		219		198		185		157
Revenue taxes		167		163		161		158
Surcharge for New York State assessment		143		90		133		82
Deferred storm costs		125		128		79		80
Net electric deferrals		116		121		116		121
Deferred derivative losses – long-term		78		60		61		44
O&R transition bond charges		43		44		—		—
Preferred stock redemption		30		—		30		—
Workers' compensation		22		23		21		23
Property tax reconciliation		13		13		—		—
Recoverable energy costs – long-term		—		14		—		14
Other		157		152		145		140
Regulatory assets – long-term		9,276		9,337		8,645		8,661
Deferred derivative losses – current		192		164		159		140
Regulatory assets – current		192		164		159		140
Total Regulatory Assets	$	9,468	$	9,501	$	8,804	$	8,801
Regulatory liabilities
Allowance for cost of removal less salvage	$	457	$	448	$	379	$	372
Property tax reconciliation		68		35		68		35
World Trade Center settlement proceeds		62		62		62		62
Net unbilled revenue deferrals		51		104		51		104
Long-term interest rate reconciliation		42		30		42		30
Carrying charges on transmission and distribution net plant		41		38		18		14
Gas line losses		17		21		17		21
Expenditure prudence proceeding		8		11		8		11
Energy efficiency programs		6		22		6		20
Other		94		206		79		192
Regulatory liabilities – long-term		846		977		730		861
Electric surcharge offset		134		—		134		—
Refundable energy costs – current		99		51		55		12
Revenue decoupling mechanism		51		66		51		66
Deferred derivative gains – current		2		1		2		1
Regulatory liabilities – current		286		118		242		79
Total Regulatory Liabilities	$	1,132	$	1,095	$	972	$	940

XML

Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2012

Regulatory Matters [Abstract]

Regulatory Assets And Liabilities

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Regulatory assets
Unrecognized pension and other postretirement costs	$	5,594	$	5,852	$	5,337	$	5,554
Future income tax		1,840		1,798		1,764		1,724
Environmental remediation costs		729		681		613		564
Pension and other post retirement benefits deferrals		219		198		185		157
Revenue taxes		167		163		161		158
Surcharge for New York State assessment		143		90		133		82
Deferred storm costs		125		128		79		80
Net electric deferrals		116		121		116		121
Deferred derivative losses – long-term		78		60		61		44
O&R transition bond charges		43		44		—		—
Preferred stock redemption		30		—		30		—
Workers' compensation		22		23		21		23
Property tax reconciliation		13		13		—		—
Recoverable energy costs – long-term		—		14		—		14
Other		157		152		145		140
Regulatory assets – long-term		9,276		9,337		8,645		8,661
Deferred derivative losses – current		192		164		159		140
Regulatory assets – current		192		164		159		140
Total Regulatory Assets	$	9,468	$	9,501	$	8,804	$	8,801
Regulatory liabilities
Allowance for cost of removal less salvage	$	457	$	448	$	379	$	372
Property tax reconciliation		68		35		68		35
World Trade Center settlement proceeds		62		62		62		62
Net unbilled revenue deferrals		51		104		51		104
Long-term interest rate reconciliation		42		30		42		30
Carrying charges on transmission and distribution net plant		41		38		18		14
Gas line losses		17		21		17		21
Expenditure prudence proceeding		8		11		8		11
Energy efficiency programs		6		22		6		20
Other		94		206		79		192
Regulatory liabilities – long-term		846		977		730		861
Electric surcharge offset		134		—		134		—
Refundable energy costs – current		99		51		55		12
Revenue decoupling mechanism		51		66		51		66
Deferred derivative gains – current		2		1		2		1
Regulatory liabilities – current		286		118		242		79
Total Regulatory Liabilities	$	1,132	$	1,095	$	972	$	940

XML

Derivative Instruments And Hedging Activities

3 Months Ended

Mar. 31, 2012

Derivative Instruments And Hedging Activities

Note J — 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 the Companies' commodity derivatives at March 31, 2012 and December 31, 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Fair value of net derivative assets/(liabilities) – gross	$	(331	)	$	(249	)	$	(181	)	$	(144	)
Impact of netting of cash collateral		156			110			64			46
Fair value of net derivative assets/(liabilities) – net	$	(175	)	$	(139	)	$	(117	)	$	(98	)

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 March 31, 2012, Con Edison and CECONY had $121 million and $12 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison's net credit exposure consisted of $46 million with investment-grade counterparties, $37 million with commodity exchange brokers, $36 million with independent system operators and $2 million with non-rated counterparties. CECONY's 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 March 31, 2012 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivatives Asset
Current	Other current assets	$	179		$	20
Long-term	Other deferred charges and non-current assets		25			6
Total derivatives asset		$	204		$	26
Impact of netting			(134	)		—
Net derivatives asset		$	70		$	26
Derivatives Liability
Current	Fair value of derivative liabilities	$	433		$	149
Long-term	Fair value of derivative liabilities		102			58
Total derivatives liability		$	535		$	207
Impact of netting			(290	)		(64	)
Net derivatives liability		$	245		$	143

(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, 2011 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivatives Asset
Current	Other current assets	$	139		$	16
Long-term	Other deferred charges and non-current assets		26			14
Total derivatives asset		$	165		$	30
Impact of netting			(95	)		(6	)
Net derivatives asset		$	70		$	24
Derivatives Liability
Current	Fair value of derivative liabilities	$	331		$	127
Long-term	Fair value of derivative liabilities		83			48
Total derivatives liability		$	414		$	175
Impact of netting			(205	)		(53	)
Net derivatives liability		$	209		$	122

(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 table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three months ended March 31, 2012:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended March 31, 2012
(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	$	1		$	1
Total deferred gains		$	1		$	1
Current	Deferred derivative losses	$	(28	)	$	(19	)
Current	Recoverable energy costs		(74	)		(56	)
Long-term	Regulatory assets		(18	)		(17	)
Total deferred losses		$	(120	)	$	(92	)
Net deferred losses		$	(119	)	$	(91	)
	Income Statement Location
Pre-tax loss recognized in income
	Purchased power expense	$	(86	)(b)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		(3	)(b)		—
Total pre-tax loss recognized in income		$	(90	)	$	—

(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 March 31, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax loss of $(4) million and $(27) million, respectively.

The following table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three months ended March 31, 2011:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended March 31, 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	$	6		$	5
Long-term	Regulatory liabilities		3			3
Total deferred gains		$	9		$	8
Current	Deferred derivative losses	$	44		$	35
Current	Recoverable energy costs		(49	)		(42	)
Long-term	Regulatory assets		17			11
Total deferred losses		$	12		$	4
Net deferred losses		$	21		$	12
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(21	)(b)	$	—
	Gas purchased for resale		(6	)		—
	Non-utility revenue		10	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(17	)	$	—

(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 March 31, 2011, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $50 million, respectively.

As of March 31, 2012, Con Edison had 1,392 contracts, including 582 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		754		16,197,114		59		7,639		579		91,840,940		1,392
CECONY		141		3,771,625		—		—		441		84,940,000		582

(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 March 31, 2012, 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	$	245		$	143
Collateral posted	$	64		$	51
Additional collateral (b) (downgrade one level from current ratings (c))	$	35		$	18
Additional collateral (b) (downgrade to below investment grade from current ratings (c))	$	225	(d)	$	106	(d)

(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 March 31, 2012, would have amounted to an estimated $39 million for Con Edison, including $9 million for CECONY. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) 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.

(d) Derivative instruments that are net assets have been excluded from the table. At March 31, 2012, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of not more than $23 million.

Interest Rate Swaps

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 March 31, 2012 was an unrealized loss of $8 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 months ended March 31, 2012 was immaterial. 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 J — 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 the Companies' commodity derivatives at March 31, 2012 and December 31, 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Fair value of net derivative assets/(liabilities) – gross	$	(331	)	$	(249	)	$	(181	)	$	(144	)
Impact of netting of cash collateral		156			110			64			46
Fair value of net derivative assets/(liabilities) – net	$	(175	)	$	(139	)	$	(117	)	$	(98	)

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 March 31, 2012, Con Edison and CECONY had $121 million and $12 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison's net credit exposure consisted of $46 million with investment-grade counterparties, $37 million with commodity exchange brokers, $36 million with independent system operators and $2 million with non-rated counterparties. CECONY's 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 March 31, 2012 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivatives Asset
Current	Other current assets	$	179		$	20
Long-term	Other deferred charges and non-current assets		25			6
Total derivatives asset		$	204		$	26
Impact of netting			(134	)		—
Net derivatives asset		$	70		$	26
Derivatives Liability
Current	Fair value of derivative liabilities	$	433		$	149
Long-term	Fair value of derivative liabilities		102			58
Total derivatives liability		$	535		$	207
Impact of netting			(290	)		(64	)
Net derivatives liability		$	245		$	143

(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, 2011 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivatives Asset
Current	Other current assets	$	139		$	16
Long-term	Other deferred charges and non-current assets		26			14
Total derivatives asset		$	165		$	30
Impact of netting			(95	)		(6	)
Net derivatives asset		$	70		$	24
Derivatives Liability
Current	Fair value of derivative liabilities	$	331		$	127
Long-term	Fair value of derivative liabilities		83			48
Total derivatives liability		$	414		$	175
Impact of netting			(205	)		(53	)
Net derivatives liability		$	209		$	122

(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 table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three months ended March 31, 2012:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended March 31, 2012
(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	$	1		$	1
Total deferred gains		$	1		$	1
Current	Deferred derivative losses	$	(28	)	$	(19	)
Current	Recoverable energy costs		(74	)		(56	)
Long-term	Regulatory assets		(18	)		(17	)
Total deferred losses		$	(120	)	$	(92	)
Net deferred losses		$	(119	)	$	(91	)
	Income Statement Location
Pre-tax loss recognized in income
	Purchased power expense	$	(86	)(b)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		(3	)(b)		—
Total pre-tax loss recognized in income		$	(90	)	$	—

(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 March 31, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax loss of $(4) million and $(27) million, respectively.

The following table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three months ended March 31, 2011:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended March 31, 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	$	6		$	5
Long-term	Regulatory liabilities		3			3
Total deferred gains		$	9		$	8
Current	Deferred derivative losses	$	44		$	35
Current	Recoverable energy costs		(49	)		(42	)
Long-term	Regulatory assets		17			11
Total deferred losses		$	12		$	4
Net deferred losses		$	21		$	12
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(21	)(b)	$	—
	Gas purchased for resale		(6	)		—
	Non-utility revenue		10	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(17	)	$	—

(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 March 31, 2011, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $50 million, respectively.

As of March 31, 2012, Con Edison had 1,392 contracts, including 582 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		754		16,197,114		59		7,639		579		91,840,940		1,392
CECONY		141		3,771,625		—		—		441		84,940,000		582

(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 March 31, 2012, 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	$	245		$	143
Collateral posted	$	64		$	51
Additional collateral (b) (downgrade one level from current ratings (c))	$	35		$	18
Additional collateral (b) (downgrade to below investment grade from current ratings (c))	$	225	(d)	$	106	(d)

(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 March 31, 2012, would have amounted to an estimated $39 million for Con Edison, including $9 million for CECONY. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) 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.

(d) Derivative instruments that are net assets have been excluded from the table. At March 31, 2012, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of not more than $23 million.

Interest Rate Swaps

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 March 31, 2012 was an unrealized loss of $8 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 months ended March 31, 2012 was immaterial. 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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Other Postretirement Benefits

3 Months Ended

Mar. 31, 2012

Other Postretirement Benefits

Note F — Other Postretirement Benefits

Net Periodic Benefit Cost

The components of the Companies' net periodic postretirement benefit costs for the three months ended March 31, 2012 and 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost	$	7		$	6		$	5		$	5
Interest cost on accumulated other postretirement benefit obligation		18			21			16			18
Expected return on plan assets		(21	)		(22	)		(18	)		(19	)
Amortization of net actuarial loss		25			22			22			20
Amortization of prior service cost		(5	)		(2	)		(4	)		(3	)
Amortization of transition obligation		—			1			—			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	24		$	26		$	21		$	22
Cost capitalized		(8	)		(9	)		(7	)		(8	)
Cost charged		7			4			4			3
Cost charged to operating expenses	$	23		$	21		$	18		$	17

Expected Contributions

Based on estimates as of March 31, 2012, Con Edison expects to make a contribution of $87 million, including $74 million for CECONY, to the other postretirement benefit plans in 2012.

CECONY [Member]

Other Postretirement Benefits

Note F Other Postretirement Benefits

Net Periodic Benefit Cost

The components of the Companies' net periodic postretirement benefit costs for the three months ended March 31, 2012 and 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost	$	7		$	6		$	5		$	5
Interest cost on accumulated other postretirement benefit obligation		18			21			16			18
Expected return on plan assets		(21	)		(22	)		(18	)		(19	)
Amortization of net actuarial loss		25			22			22			20
Amortization of prior service cost		(5	)		(2	)		(4	)		(3	)
Amortization of transition obligation					1						1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	24		$	26		$	21		$	22
Cost capitalized		(8	)		(9	)		(7	)		(8	)
Cost charged		7			4			4			3
Cost charged to operating expenses	$	23		$	21		$	18		$	17

Expected Contributions

Based on estimates as of March 31, 2012, Con Edison expects to make a contribution of $87 million, including $74 million for CECONY, to the other postretirement benefit plans in 2012.

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Short-Term Borrowing

3 Months Ended

Mar. 31, 2012

Short-Term Borrowing

Note D — Short-Term Borrowing

At March 31, 2012, Con Edison and CECONY had no commercial paper outstanding. The Companies have not borrowed under their October 2011 credit agreement. Con Edison had $183 million of letters of credit outstanding under the credit agreement (including $168 million for CECONY).

CECONY [Member]

Short-Term Borrowing

Note D — Short-Term Borrowing

At March 31, 2012, Con Edison and CECONY had no commercial paper outstanding. The Companies have not borrowed under their October 2011 credit agreement. Con Edison had $183 million of letters of credit outstanding under the credit agreement (including $168 million for CECONY).

XML

Pension Benefits

3 Months Ended

Mar. 31, 2012

Pension Benefits

Note E — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies' net periodic benefit costs for the three months ended March 31, 2012 and 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses	$	59		$	47		$	55		$	44
Interest cost on projected benefit obligation		137			140			128			131
Expected return on plan assets		(176	)		(183	)		(168	)		(175	)
Amortization of net actuarial loss		177			132			168			125
Amortization of prior service costs		2			2			2			2
NET PERIODIC BENEFIT COST	$	199		$	138		$	185		$	127
Cost capitalized		(64	)		(48	)		(63	)		(45	)
Cost deferred		(37	)		(51	)		(38	)		(52	)
Cost charged to operating expenses	$	98		$	39		$	84		$	30

Expected Contributions

Based on estimates as of March 31, 2012, the Companies expect to make contributions to the pension plan during 2012 of $775 million (of which $721 million is to be contributed by CECONY). During the first quarter of 2012, CECONY contributed $184 million to the pension plan. The Companies expect to fund $12 million for the non-qualified supplemental plans in 2012. The Companies' policy is to fund their accounting cost to the extent tax deductible.

CECONY [Member]

Pension Benefits

Note E Pension Benefits

Net Periodic Benefit Cost

The components of the Companies' net periodic benefit costs for the three months ended March 31, 2012 and 2011 were as follows:

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost including administrative expenses	$	59		$	47		$	55		$	44
Interest cost on projected benefit obligation		137			140			128			131
Expected return on plan assets		(176	)		(183	)		(168	)		(175	)
Amortization of net actuarial loss		177			132			168			125
Amortization of prior service costs		2			2			2			2
NET PERIODIC BENEFIT COST	$	199		$	138		$	185		$	127
Cost capitalized		(64	)		(48	)		(63	)		(45	)
Cost deferred		(37	)		(51	)		(38	)		(52	)
Cost charged to operating expenses	$	98		$	39		$	84		$	30

Expected Contributions

Based on estimates as of March 31, 2012, the Companies expect to make contributions to the pension plan during 2012 of $775 million (of which $721 million is to be contributed by CECONY). During the first quarter of 2012, CECONY contributed $184 million to the pension plan. The Companies expect to fund $12 million for the non-qualified supplemental plans in 2012. The Companies' policy is to fund their accounting cost to the extent tax deductible.

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Environmental Matters

3 Months Ended

Mar. 31, 2012

Environmental Matters

Note G — Environmental Matters

Superfund Sites

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

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

For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company's share of 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 March 31, 2012 and December 31, 2011 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued Liabilities:
Manufactured gas plant sites	$	466	$	422	$	351	$	307
Other Superfund Sites		71		67		70		66
Total	$	537	$	489	$	421	$	373
Regulatory assets	$	729	$	681	$	613	$	564

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 and insurance recoveries received related to Superfund Sites for the three months ended March 31, 2012 and 2011, were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred	$	7	$	6	$	7	$	5
Insurance recoveries received		—		—		—		—

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 March 31, 2012 and December 31, 2011 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued liability – asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets – asbestos suits	$	10	$	10	$	10	$	10
Accrued liability – workers' compensation	$	96	$	98	$	92	$	93
Regulatory assets – workers' compensation	$	22	$	23	$	21	$	23

CECONY [Member]

Environmental Matters

Note G Environmental Matters

Superfund Sites

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

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

For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company's share of 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 March 31, 2012 and December 31, 2011 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued Liabilities:
Manufactured gas plant sites	$	466	$	422	$	351	$	307
Other Superfund Sites		71		67		70		66
Total	$	537	$	489	$	421	$	373
Regulatory assets	$	729	$	681	$	613	$	564

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 and insurance recoveries received related to Superfund Sites for the three months ended March 31, 2012 and 2011, were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred	$	7	$	6	$	7	$	5
Insurance recoveries received

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 March 31, 2012 and December 31, 2011 were as follows:

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued liability asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets asbestos suits	$	10	$	10	$	10	$	10
Accrued liability workers' compensation	$	96	$	98	$	92	$	93
Regulatory assets workers' compensation	$	22	$	23	$	21	$	23

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Capitalization (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Schedule of Capitalization [Line Items]
Carrying Amount	$ 11,071	$ 10,673
Fair Value	12,892	12,744
Level 2 [Member]
Schedule of Capitalization [Line Items]
Fair Value	12,256
Level 3 [Member]
Schedule of Capitalization [Line Items]
Fair Value	$ 636

XML

Fair Value Measurements (Assets And Liabilities Measured At Fair Value On A Recurring Basis) (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended						12 Months Ended			12 Months Ended						12 Months Ended						12 Months Ended			12 Months Ended																																																																													3 Months Ended																								3 Months Ended
	Dec. 31, 2011		Mar. 31, 2012	Mar. 31, 2012 Level 1 [Member]	Dec. 31, 2011 Level 1 [Member]		Dec. 31, 2011 Level 2 [Member]		Mar. 31, 2012 Level 2 [Member]	Dec. 31, 2011 Level 3 [Member]		Mar. 31, 2012 Level 3 [Member]	Mar. 31, 2012 Netting Adjustments [Member]	Dec. 31, 2011 Netting Adjustments [Member]		Dec. 31, 2011 CECONY [Member]		Mar. 31, 2012 CECONY [Member]	Mar. 31, 2012 CECONY [Member] Level 1 [Member]	Dec. 31, 2011 CECONY [Member] Level 1 [Member]		Dec. 31, 2011 CECONY [Member] Level 2 [Member]		Mar. 31, 2012 CECONY [Member] Level 2 [Member]	Dec. 31, 2011 CECONY [Member] Level 3 [Member]		Mar. 31, 2012 CECONY [Member] Level 3 [Member]	Mar. 31, 2012 CECONY [Member] Netting Adjustments [Member]	Dec. 31, 2011 CECONY [Member] Netting Adjustments [Member]		Mar. 31, 2012 Commodity [Member]		Dec. 31, 2011 Commodity [Member]		Mar. 31, 2012 Commodity [Member] Level 1 [Member]		Dec. 31, 2011 Commodity [Member] Level 1 [Member]		Mar. 31, 2012 Commodity [Member] Level 2 [Member]		Dec. 31, 2011 Commodity [Member] Level 2 [Member]		Mar. 31, 2012 Commodity [Member] Level 3 [Member]		Dec. 31, 2011 Commodity [Member] Level 3 [Member]		Mar. 31, 2012 Commodity [Member] Netting Adjustments [Member]		Dec. 31, 2011 Commodity [Member] Netting Adjustments [Member]		Mar. 31, 2012 Commodity [Member] CECONY [Member]		Dec. 31, 2011 Commodity [Member] CECONY [Member]		Mar. 31, 2012 Commodity [Member] CECONY [Member] Level 1 [Member]		Dec. 31, 2011 Commodity [Member] CECONY [Member] Level 1 [Member]	Mar. 31, 2012 Commodity [Member] CECONY [Member] Level 2 [Member]		Dec. 31, 2011 Commodity [Member] CECONY [Member] Level 2 [Member]		Mar. 31, 2012 Commodity [Member] CECONY [Member] Level 3 [Member]		Dec. 31, 2011 Commodity [Member] CECONY [Member] Level 3 [Member]		Mar. 31, 2012 Commodity [Member] CECONY [Member] Netting Adjustments [Member]		Dec. 31, 2011 Commodity [Member] CECONY [Member] Netting Adjustments [Member]		Mar. 31, 2012 Other Assets [Member]		Dec. 31, 2011 Other Assets [Member]		Mar. 31, 2012 Other Assets [Member] Level 1 [Member]		Dec. 31, 2011 Other Assets [Member] Level 1 [Member]		Mar. 31, 2012 Other Assets [Member] Level 3 [Member]		Dec. 31, 2011 Other Assets [Member] Level 3 [Member]		Mar. 31, 2012 Other Assets [Member] CECONY [Member]		Dec. 31, 2011 Other Assets [Member] CECONY [Member]		Mar. 31, 2012 Other Assets [Member] CECONY [Member] Level 1 [Member]		Dec. 31, 2011 Other Assets [Member] CECONY [Member] Level 1 [Member]		Mar. 31, 2012 Other Assets [Member] CECONY [Member] Level 3 [Member]		Dec. 31, 2011 Other Assets [Member] CECONY [Member] Level 3 [Member]		Mar. 31, 2012 Interest Rate Contract [Member]		Dec. 31, 2011 Interest Rate Contract [Member]		Mar. 31, 2012 Interest Rate Contract [Member] Level 3 [Member]		Dec. 31, 2011 Interest Rate Contract [Member] Level 3 [Member]		Mar. 31, 2012 Derivatives Assets [Member]		Mar. 31, 2012 Derivatives Assets [Member] Level 2 [Member]		Mar. 31, 2012 Derivatives Assets [Member] Level 3 [Member]		Mar. 31, 2012 Derivatives Assets [Member] CECONY [Member]		Mar. 31, 2012 Derivatives Assets [Member] CECONY [Member] Level 2 [Member]		Mar. 31, 2012 Derivatives Assets [Member] CECONY [Member] Level 3 [Member]		Mar. 31, 2012 Derivatives Assets [Member] Other Assets [Member]		Mar. 31, 2012 Derivatives Assets [Member] Other Assets [Member] Level 1 [Member]		Mar. 31, 2012 Derivatives Assets [Member] Other Assets [Member] Level 2 [Member]		Mar. 31, 2012 Derivatives Assets [Member] Other Assets [Member] CECONY [Member]		Mar. 31, 2012 Derivatives Assets [Member] Other Assets [Member] CECONY [Member] Level 1 [Member]		Mar. 31, 2012 Derivatives Assets [Member] Other Assets [Member] CECONY [Member] Level 2 [Member]		Mar. 31, 2012 Derivatives Liabilities [Member]		Mar. 31, 2012 Derivatives Liabilities [Member] Level 2 [Member]		Mar. 31, 2012 Derivatives Liabilities [Member] Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets																															$ 69	[1]	$ 70	[1]	$ 2	[1]	$ 3	[1]	$ 86	[1]	$ 64	[1]	$ 103	[1]	$ 87	[1]	$ (122)	[1]	$ (84)	[1]	$ 26	[1]	$ 24	[1]				$ 4	[1]	$ 8	[1]	$ 13	[1]	$ 11	[1]	$ 9	[1]	$ 5	[1]	$ 188	[2]	$ 175	[2]	$ 83	[2]	$ 76	[2]	$ 105	[2]	$ 99	[2]	$ 178	[2]	$ 166	[2]	$ 83	[2]	$ 76	[2]	$ 95	[2]	$ 90	[2]																					$ 188	[2]	$ 83	[2]	$ 105	[2]	$ 178	[2]	$ 83	[2]	$ 95	[2]
Total assets	245		257	85	79		64		191	186		103	(122)	(84)		190		204	83	76		8		99	101		13	9	5
Transfer in	32	[3],[4],[5]					26	[3],[4],[5]		6	[3],[4],[5]					31	[3],[4],[5]					25	[3],[4],[5]		6	[3],[4],[5]																																																																												105	[3],[6]	105	[3],[6]			95	[3],[6]	95	[3],[6]															8	[3],[6]	8	[3],[6]
Transfer out	(32)	[3],[4],[5]					(6)	[3],[4],[5]		(26)	[3],[4],[5]					(31)	[3],[4],[5]					(6)	[3],[4],[5]		(25)	[3],[4],[5]																																																																												(105)	[3],[6]			(105)	[3],[6]	(95)	[3],[6]			(95)	[3],[6]													(8)	[3],[6]			(8)	[3],[6]
Derivative liabilities	209	[1]			12	[1]	242	[1]		149	[1]			(194)	[1]	122	[1]			4	[1]	141	[1]		18	[1]			(41)	[1]	244	[1]	209		10	[1]	12		316	[1]	222		196	[1]	169		(278)	[1]	(194)		143	[1]	122		2	[1]	4	170	[1]	122		26	[1]	37		(55)	[1]	(41)																										8	[7]	8	[7]	8	[7]	8	[7]
Total liabilities	$ 217		$ 252	$ 10	$ 12		$ 242		$ 324	$ 157		$ 196	$ (278)	$ (194)		$ 122		$ 143	$ 2	$ 4		$ 141		$ 170	$ 18		$ 26	$ (55)	$ (41)

[1] A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

[2] Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans.

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

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

[5] 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 December 31, 2011.

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

[7] See Note J.

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Summary Of Significant Accounting Policies (Policy)

3 Months Ended

Mar. 31, 2012

Summary Of Significant Accounting Policies [Abstract]

Earnings Per Common Share

Earnings Per Common Share

For the three months ended March 31, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011
Net income for common stock	$	277	$	311
Weighted average common shares outstanding – Basic		292.9		292.0
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		293.6
Net income for common stock per common share – basic	$	0.95	$	1.07
Net income for common stock per common share – diluted	$	0.94	$	1.06

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

3 Months Ended

Mar. 31, 2012

Other Postretirement Benefits [Member]

Defined Benefit Plan Disclosure [Line Items]

Net Periodic Postretirement Benefit Costs

	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost	$	7		$	6		$	5		$	5
Interest cost on accumulated other postretirement benefit obligation		18			21			16			18
Expected return on plan assets		(21	)		(22	)		(18	)		(19	)
Amortization of net actuarial loss		25			22			22			20
Amortization of prior service cost		(5	)		(2	)		(4	)		(3	)
Amortization of transition obligation		—			1			—			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	24		$	26		$	21		$	22
Cost capitalized		(8	)		(9	)		(7	)		(8	)
Cost charged		7			4			4			3
Cost charged to operating expenses	$	23		$	21		$	18		$	17

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Derivative Instruments And Hedging Activities (Aggregate Fair Value Of All Derivative Instruments With Credit-Risk-Related Contingent Features) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012
Derivatives, Fair Value [Line Items]
Aggregate fair value - net liabilities	$ 245	[1]
Collateral posted	64	[1]
Additional Collateral Required Due To Loss Of Unsecured Credit [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	39
Additional collateral	35	[1],[2],[3]
Additional Collateral Aggregate Fair Value Down Below Investment Grade [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	23
Additional collateral	$ 225	[1],[2],[3],[4]

[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 March 31, 2012, would have amounted to an estimated $39 million for Con Edison, including $9 million for CECONY. 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] 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.

[3] 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.

[4] Derivative instruments that are net assets have been excluded from the table. At March 31, 2012, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of not more than $23 million.

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Other Material Contingencies (Narrative) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2012 Tax Deficiency Paid In December 2005 [Member]	Mar. 31, 2012 Interest In April 2006 [Member]	Mar. 31, 2012 Disallowance Of Tax 1998-2007 [Member]	Dec. 31, 2010 Disallowance Of Tax 2010 [Member]	Dec. 31, 2009 Disallowance Of Tax 2009 [Member]	Dec. 31, 2008 Disallowance Of Tax 2008 [Member]
Operating Leased Assets [Line Items]
Total investment in electric generating and gas distribution facilities	$ 259
Transactions financed with equity	93
Transactions financed with non-recourse	166
The company's investment in leveraged leases	(65)	(55)
Gross investment in leverage leases	228	234
Deferred tax liabilities	293	289
Tax deficiency paid to IRS			0.3
Interest paid related to tax deficiency				0.2
Disallowed deduction					416	40	41	42
Tax savings from lease in lease out transactions	240
Interest paid	114
Guarantee obligations maximum exposure	$ 760	$ 760

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Consolidated Statement Of Cash Flows (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
OPERATING ACTIVITIES
Net Income	$ 280	$ 314
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	233	218
Deferred income taxes	68	232
Rate case amortization and accruals	31	19
Common equity component of allowance for funds used during construction		(4)
Net derivative losses/(gains)	31	(37)
Other non-cash items (net)	64	(17)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	54	(5)
Materials and supplies, including fuel oil and gas in storage	31	103
Other receivables and other current assets	(2)	66
Prepayments	(286)	(217)
Accounts payable	(78)	(154)
Pensions and retiree benefits obligations	253	259
Pensions and retiree benefits contribution	(184)	(491)
Accrued taxes	41	(20)
Accrued interest	52	51
Deferred charges, noncurrent assets and other regulatory assets	(255)	(19)
Deferred credits and other regulatory liabilities	117	67
Other assets		(1)
Other liabilities	(48)	(2)
NET CASH FLOWS FROM OPERATING ACTIVITIES	402	362
INVESTING ACTIVITIES
Utility construction expenditures	(471)	(394)
Cost of removal less salvage	(43)	(39)
Non-utility construction expenditures	(9)	(23)
Proceeds from investment tax credits and grants related to renewable energy investments	6
Net investment in Pilesgrove solar project and other	27
Loan to affiliate		(40)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(490)	(496)
FINANCING ACTIVITIES
Net proceeds from short-term debt		464
Retirement of long-term debt	(1)	(1)
Issuance of long-term debt	400
Issuance of common shares for stock plans, net of repurchases	(8)	25
Debt issuance costs	(4)
Common stock dividends	(175)	(173)
Preferred stock dividends	(3)	(3)
NET CASH FLOWS FROM FINANCING ACTIVITIES	209	312
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	121	178
BALANCE AT BEGINNING OF PERIOD	648	338
BALANCE AT END OF PERIOD	769	516
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest	89	90
Income taxes		(172)
CECONY [Member]
OPERATING ACTIVITIES
Net Income	276	271
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	218	204
Deferred income taxes	66	207
Rate case amortization and accruals	31	19
Common equity component of allowance for funds used during construction		(3)
Other non-cash items (net)	15	10
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	43	22
Materials and supplies, including fuel oil and gas in storage	22	84
Other receivables and other current assets	16	(77)
Prepayments	(287)	(291)
Accounts payable	(48)	(119)
Pensions and retiree benefits obligations	209	236
Pensions and retiree benefits contribution	(184)	(491)
Accrued taxes	57	(37)
Accrued interest	42	44
Superfund and environmental remediation costs (net)	(1)
Deferred charges, noncurrent assets and other regulatory assets	(179)	(63)
Deferred credits and other regulatory liabilities	108	52
Other liabilities	(36)	4
NET CASH FLOWS FROM OPERATING ACTIVITIES	368	72
INVESTING ACTIVITIES
Utility construction expenditures	(446)	(376)
Cost of removal less salvage	(41)	(37)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(487)	(413)
FINANCING ACTIVITIES
Net proceeds from short-term debt		464
Issuance of long-term debt	400
Debt issuance costs	(4)
Dividend to parent	(171)	(170)
Preferred stock dividends	(3)	(3)
NET CASH FLOWS FROM FINANCING ACTIVITIES	222	291
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	103	(50)
BALANCE AT BEGINNING OF PERIOD	372	78
BALANCE AT END OF PERIOD	475	28
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest	83	82
Income taxes	$ (20)	$ 35

XML

Summary Of Significant Accounting Policies

3 Months Ended

Mar. 31, 2012

Summary Of Significant Accounting Policies

Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

For the three months ended March 31, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011
Net income for common stock	$	277	$	311
Weighted average common shares outstanding – Basic		292.9		292.0
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		293.6
Net income for common stock per common share – basic	$	0.95	$	1.07
Net income for common stock per common share – diluted	$	0.94	$	1.06

CECONY [Member]

Summary Of Significant Accounting Policies

Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

For the three months ended March 31, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011
Net income for common stock	$	277	$	311
Weighted average common shares outstanding – Basic		292.9		292.0
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		293.6
Net income for common stock per common share – basic	$	0.95	$	1.07
Net income for common stock per common share – diluted	$	0.94	$	1.06

XML

Environmental Matters (Tables)

3 Months Ended

Mar. 31, 2012

Environmental Matters [Abstract]

Accrued Liabilities And Regulatory Assets

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued Liabilities:
Manufactured gas plant sites	$	466	$	422	$	351	$	307
Other Superfund Sites		71		67		70		66
Total	$	537	$	489	$	421	$	373
Regulatory assets	$	729	$	681	$	613	$	564

Environmental Remediation Costs

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred	$	7	$	6	$	7	$	5
Insurance recoveries received		—		—		—		—

Accrued Liability For Asbestos Suits And Workers' Compensation Proceedings

	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued liability – asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets – asbestos suits	$	10	$	10	$	10	$	10
Accrued liability – workers' compensation	$	96	$	98	$	92	$	93
Regulatory assets – workers' compensation	$	22	$	23	$	21	$	23

XML

Environmental Matters (Accrued Liabilities And Regulatory Assets) (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Site Contingency [Line Items]
Regulatory assets	$ 9,468	$ 9,501
Manufactured Gas Plant Sites [Member]
Site Contingency [Line Items]
Accrued liabilities	466	422
Other Superfund Sites [Member]
Site Contingency [Line Items]
Accrued liabilities	71	67
Superfund Sites [Member]
Site Contingency [Line Items]
Accrued liabilities	537	489
Regulatory assets	$ 729	$ 681

XML

Fair Value Measurements

3 Months Ended

Mar. 31, 2012

Fair Value Measurements

Note K — 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.

Effective January 1, 2012, the Companies adopted 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 existing disclosure requirements for fair value measurements and make other amendments. For fair value measurements in Level 3, this update requires the Companies to provide a description of the valuation process in place, a quantitative disclosure of unobservable inputs and assumptions used in the measurement as well as a narrative description of the sensitivity of the fair value to changes in unobservable inputs and interrelationships between those inputs. The update also requires the Companies to disclose any transfers between Levels 1 and 2 of fair value hierarchy measurements and the reasons for the transfers.

Assets and liabilities measured at fair value on a recurring basis as of March 31, 2012 are summarized below.

	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	$	—	$	86	$	4	$	103		$	13		$	(122	)	$	9		$	69		$	26
Other assets (3)		83		83		—		—		105			95			—			—			188			178
Transfer in (5) (6)		—		—		105		95		—			—			—			—			105			95
Transfer out (5) (6)		—		—		—		—		(105	)		(95	)		—			—			(105	)		(95	)
Other assets (3)	$	83	$	83	$	105	$	95	$	—		$	—		$	—		$	—		$	188		$	178
Total	$	85	$	83	$	191	$	99	$	103		$	13		$	(122	)	$	9		$	257		$	204
Derivative liabilities:
Commodity (1)	$	10	$	2	$	316	$	170	$	196		$	26		$	(278	)	$	(55	)	$	244		$	143
Interest rate contract (2)		—		—		—		—		8			—			—			—			8			—
Transfer in (5) (6)		—		—		8		—		—			—			—			—			8			—
Transfer out (5) (6)		—		—		—		—		(8	)		—			—			—			(8	)		—
Interest rate contract (2)	$	—	$	—	$	8	$	—	$	—		$	—		$	—		$	—		$	8		$	—
Total	$	10	$	2	$	324	$	170	$	196		$	26		$	(278	)	$	(55	)	$	252		$	143

(1) A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

(2) See Note J.

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

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

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2011 are summarized below.

	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)	$	3	$	—	$	64		$	8		$	87		$	11		$	(84	)	$	5		$	70		$	24
Other assets (3)		76		76		—			—			99			90			—			—			175			166
Total	$	79	$	76	$	64		$	8		$	186		$	101		$	(84	)	$	5		$	245		$	190
Derivative liabilities:
Commodity	$	12	$	4	$	222		$	122		$	169		$	37		$	(194	)	$	(41	)	$	209		$	122
Transfer in (5) (6) (7)		—		—		26			25			6			6			—			—			32			31
Transfer out (5) (6) (7)		—		—		(6	)		(6	)		(26	)		(25	)		—			—			(32	)		(31	)
Commodity (1)	$	12	$	4	$	242		$	141		$	149		$	18		$	(194	)	$	(41	)	$	209		$	122
Interest rate contract (2)		—		—		—			—			8			—			—			—			8			—
Total	$	12	$	4	$	242		$	141		$	157		$	18		$	(194	)	$	(41	)	$	217		$	122

(1) A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

(2) See Note J.

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

(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, 2010 to less than one year as of December 31, 2011.

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

(Millions of Dollars)	Fair Value of Level 3 at 3/31/2012			Valuation Techniques	Unobservable Inputs
Con Edison
Commodity	$	(93	)	Market approach (1)	Discount for inactive markets and/or illiquid locations (2)
CECONY
Commodity	$	(13	)	Market approach (1)	Discount for inactive markets and/or illiquid locations (2)

(1) The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets and liabilities. The commodity derivatives are valued using quoted prices or internally developed models with observable inputs, adjusted for certain contracts that are traded in inactive markets and/or at illiquid locations. The unobservable inputs used in the Companies' models do not have a significant impact on the valuation.

(2) Significant increases or decreases in any of these inputs in isolation would have a limited impact on fair value measurement. Generally, a change in the fair value measurement is linearly based on changes in these inputs.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of March 31, 2012 and 2011 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended March 31, 2012
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2012			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of March 31, 2012
Con Edison
Derivatives:
Commodity	$	(62	)	$	(58	)	$	(17	)	$	6	$	—	$	—	$	38	$	—		$	(93	)
Interest rate contract		(8	)		(1	)		—			—		—		—		1		8			—
Other assets (1)		99			3			3			—		—		—		—		(105	)		—
Total	$	29		$	(56	)	$	(14	)	$	6	$	—	$	—	$	39	$	(97	)	$	(93	)
CECONY
Derivatives:
Commodity	$	(7	)	$	(5	)	$	(7	)	$	6	$	—	$	—	$	—	$	—		$	(13	)
Other assets (1)		90			3			2			—		—		—		—		(95	)		—
Total	$	83		$	(2	)	$	(5	)	$	6	$	—	$	—	$	—	$	(95	)	$	(13	)

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

	For the Three Months Ended March 31, 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 March 31, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	9		$	40	$	10	$	—	$	—	$	3		$	(5	)	$	(31	)
Interest rate contract		(10	)		(1	)		—		—		—		—		1			—			(10	)
Other assets (1)		101			2			2		—		—		—		—			—			105
Total	$	3		$	10		$	42	$	10	$	—	$	—	$	4		$	(5	)	$	64
CECONY
Derivatives:
Commodity	$	(26	)	$	(1	)	$	27	$	10	$	—	$	—	$	(3	)	$	(5	)	$	2
Other assets (1)		92			2			1		—		—		—		—			—			95
Total	$	66		$	1		$	28	$	10	$	—	$	—	$	(3	)	$	(5	)	$	97

(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. See Note A to the financial statements in Item 8 of the Form 10-K. 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 ($3 million loss and $12 million loss) and purchased power costs ($43 million loss and $27 million gain) on the consolidated income statement for the three months ended March 31, 2012 and 2011, respectively. The change in fair value relating to Level 3 commodity derivative assets held at March 31, 2012 and 2011 is included in non-utility revenues ($3 million loss and $12 million loss), and purchased power costs ($7 million loss and $29 million gain) on the consolidated income statement for the three months ended March 31, 2012 and 2011, respectively.

The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At March 31, 2012, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. To assess nonperformance 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 (for an asset) or the Companies' (for a liability) credit default swaps rates.

CECONY [Member]

Fair Value Measurements

Note K — 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.

Effective January 1, 2012, the Companies adopted 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 existing disclosure requirements for fair value measurements and make other amendments. For fair value measurements in Level 3, this update requires the Companies to provide a description of the valuation process in place, a quantitative disclosure of unobservable inputs and assumptions used in the measurement as well as a narrative description of the sensitivity of the fair value to changes in unobservable inputs and interrelationships between those inputs. The update also requires the Companies to disclose any transfers between Levels 1 and 2 of fair value hierarchy measurements and the reasons for the transfers.

Assets and liabilities measured at fair value on a recurring basis as of March 31, 2012 are summarized below.

	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	$	—	$	86	$	4	$	103		$	13		$	(122	)	$	9		$	69		$	26
Other assets (3)		83		83		—		—		105			95			—			—			188			178
Transfer in (5) (6)		—		—		105		95		—			—			—			—			105			95
Transfer out (5) (6)		—		—		—		—		(105	)		(95	)		—			—			(105	)		(95	)
Other assets (3)	$	83	$	83	$	105	$	95	$	—		$	—		$	—		$	—		$	188		$	178
Total	$	85	$	83	$	191	$	99	$	103		$	13		$	(122	)	$	9		$	257		$	204
Derivative liabilities:
Commodity (1)	$	10	$	2	$	316	$	170	$	196		$	26		$	(278	)	$	(55	)	$	244		$	143
Interest rate contract (2)		—		—		—		—		8			—			—			—			8			—
Transfer in (5) (6)		—		—		8		—		—			—			—			—			8			—
Transfer out (5) (6)		—		—		—		—		(8	)		—			—			—			(8	)		—
Interest rate contract (2)	$	—	$	—	$	8	$	—	$	—		$	—		$	—		$	—		$	8		$	—
Total	$	10	$	2	$	324	$	170	$	196		$	26		$	(278	)	$	(55	)	$	252		$	143

(1) A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

(2) See Note J.

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

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

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2011 are summarized below.

	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)	$	3	$	—	$	64		$	8		$	87		$	11		$	(84	)	$	5		$	70		$	24
Other assets (3)		76		76		—			—			99			90			—			—			175			166
Total	$	79	$	76	$	64		$	8		$	186		$	101		$	(84	)	$	5		$	245		$	190
Derivative liabilities:
Commodity	$	12	$	4	$	222		$	122		$	169		$	37		$	(194	)	$	(41	)	$	209		$	122
Transfer in (5) (6) (7)		—		—		26			25			6			6			—			—			32			31
Transfer out (5) (6) (7)		—		—		(6	)		(6	)		(26	)		(25	)		—			—			(32	)		(31	)
Commodity (1)	$	12	$	4	$	242		$	141		$	149		$	18		$	(194	)	$	(41	)	$	209		$	122
Interest rate contract (2)		—		—		—			—			8			—			—			—			8			—
Total	$	12	$	4	$	242		$	141		$	157		$	18		$	(194	)	$	(41	)	$	217		$	122

(1) A portion of the commodity derivatives categorized in Level 3 is valued using 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 J.

(2) See Note J.

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

(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, 2010 to less than one year as of December 31, 2011.

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

(Millions of Dollars)	Fair Value of Level 3 at 3/31/2012			Valuation Techniques	Unobservable Inputs
Con Edison
Commodity	$	(93	)	Market approach (1)	Discount for inactive markets and/or illiquid locations (2)
CECONY
Commodity	$	(13	)	Market approach (1)	Discount for inactive markets and/or illiquid locations (2)

(1) The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets and liabilities. The commodity derivatives are valued using quoted prices or internally developed models with observable inputs, adjusted for certain contracts that are traded in inactive markets and/or at illiquid locations. The unobservable inputs used in the Companies' models do not have a significant impact on the valuation.

(2) Significant increases or decreases in any of these inputs in isolation would have a limited impact on fair value measurement. Generally, a change in the fair value measurement is linearly based on changes in these inputs.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of March 31, 2012 and 2011 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended March 31, 2012
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2012			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of March 31, 2012
Con Edison
Derivatives:
Commodity	$	(62	)	$	(58	)	$	(17	)	$	6	$	—	$	—	$	38	$	—		$	(93	)
Interest rate contract		(8	)		(1	)		—			—		—		—		1		8			—
Other assets (1)		99			3			3			—		—		—		—		(105	)		—
Total	$	29		$	(56	)	$	(14	)	$	6	$	—	$	—	$	39	$	(97	)	$	(93	)
CECONY
Derivatives:
Commodity	$	(7	)	$	(5	)	$	(7	)	$	6	$	—	$	—	$	—	$	—		$	(13	)
Other assets (1)		90			3			2			—		—		—		—		(95	)		—
Total	$	83		$	(2	)	$	(5	)	$	6	$	—	$	—	$	—	$	(95	)	$	(13	)

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

	For the Three Months Ended March 31, 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 March 31, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	9		$	40	$	10	$	—	$	—	$	3		$	(5	)	$	(31	)
Interest rate contract		(10	)		(1	)		—		—		—		—		1			—			(10	)
Other assets (1)		101			2			2		—		—		—		—			—			105
Total	$	3		$	10		$	42	$	10	$	—	$	—	$	4		$	(5	)	$	64
CECONY
Derivatives:
Commodity	$	(26	)	$	(1	)	$	27	$	10	$	—	$	—	$	(3	)	$	(5	)	$	2
Other assets (1)		92			2			1		—		—		—		—			—			95
Total	$	66		$	1		$	28	$	10	$	—	$	—	$	(3	)	$	(5	)	$	97

(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. See Note A to the financial statements in Item 8 of the Form 10-K. 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 ($3 million loss and $12 million loss) and purchased power costs ($43 million loss and $27 million gain) on the consolidated income statement for the three months ended March 31, 2012 and 2011, respectively. The change in fair value relating to Level 3 commodity derivative assets held at March 31, 2012 and 2011 is included in non-utility revenues ($3 million loss and $12 million loss), and purchased power costs ($7 million loss and $29 million gain) on the consolidated income statement for the three months ended March 31, 2012 and 2011, respectively.

The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At March 31, 2012, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. To assess nonperformance 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 (for an asset) or the Companies' (for a liability) credit default swaps rates.