10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 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 October 31, 2012, Con Edison had outstanding 292,872,896 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
AC	Alternating current
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
Second Quarter Form 10-Q	The Companies’ combined Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2012
Third Quarter Form 10-Q	The Companies’ combined Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2012
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		40
ITEM 3	Quantitative and Qualitative Disclosures About Market Risk		63
ITEM 4	Controls and Procedures		63
PART II—Other Information
ITEM 1	Legal Proceedings		64
ITEM 1A	Risk Factors		64
ITEM 2	Unregistered Sales of Equity Securities and Use of Proceeds		64
ITEM 6	Exhibits		65
	Signatures		66

4

FORWARD-LOOKING STATEMENTS

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

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

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

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

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

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

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

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

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

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

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

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

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

• a cyber attack could adversely affect the Companies; and

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

5

Consolidated Edison, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2012			2011			2012			2011
	(Millions of Dollars/Except Share Data)
OPERATING REVENUES
Electric		$2,810			$2,861			$6,762			$6,883
Gas		216			220			1,161			1,309
Steam		68			76			414			508
Non-utility		344			472			950			1,272
TOTAL OPERATING REVENUES		3,438			3,629			9,287			9,972
OPERATING EXPENSES
Purchased power		930			1,239			2,440			3,124
Fuel		59			73			213			317
Gas purchased for resale		56			73			314			491
Operations and maintenance		826			783			2,365			2,213
Depreciation and amortization		240			222			709			659
Taxes, other than income taxes		476			483			1,360			1,387
TOTAL OPERATING EXPENSES		2,587			2,873			7,401			8,191
OPERATING INCOME		851			756			1,886			1,781
OTHER INCOME (DEDUCTIONS)
Investment and other income		4			—			14			19
Allowance for equity funds used during construction		1			2			3			8
Other deductions		(3	)		(3	)		(13	)		(14	)
TOTAL OTHER INCOME (DEDUCTIONS)		2			(1	)		4			13
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE		853			755			1,890			1,794
INTEREST EXPENSE
Interest on long-term debt		146			145			440			437
Other interest		6			—			17			15
Allowance for borrowed funds used during construction		—			(1	)		(2	)		(4	)
NET INTEREST EXPENSE		152			144			455			448
INCOME BEFORE INCOME TAX EXPENSE		701			611			1,435			1,346
INCOME TAX EXPENSE		261			225			501			477
NET INCOME		440			386			934			869
Preferred stock dividend requirements of subsidiary		—			(3	)		(3	)		(9	)
NET INCOME FOR COMMON STOCK		$440			$383			$931			$860
Net income for common stock per common share—basic		$1.50			$1.31			$3.18			$2.94
Net income for common stock per common share—diluted		$1.49			$1.30			$3.16			$2.92
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK		$0.605			$0.600			$1.815			$1.800
AVERAGE NUMBER OF SHARES OUTSTANDING—BASIC (IN MILLIONS)		292.9			292.9			292.9			292.5
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS)		294.6			294.6			294.6			294.2

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

6

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended September 30,					For the Nine Months Ended September 30,
	2012		2011			2012			2011
	(Millions of Dollars)
NET INCOME		$440		$386			$934			$869
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension plan liability adjustments, net of $1 and $5 taxes in 2012 and $1 and $4 in taxes 2011, respectively		2		2			8			7
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES		2		2			8			7
COMPREHENSIVE INCOME		$442		$388			$942			$876
Preferred stock dividend requirements of subsidiary		—		(3	)		(3	)		(9	)
COMPREHENSIVE INCOME FOR COMMON STOCK		$442		$385			$939			$867

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

7

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Nine Months Ended September 30,
	2012			2011
	(Millions of Dollars)
OPERATING ACTIVITIES
Net Income		$    934			$    869
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization		709			659
Deferred income taxes		344			368
Rate case amortization and accruals		32			39
Common equity component of allowance for funds used during construction		(3	)		(8	)
Net derivative gains		(61	)		(25	)
Other non-cash items (net)		(53	)		6
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers, less allowance for uncollectibles		(196	)		(4	)
Materials and supplies, including fuel oil and gas in storage		1			(27	)
Other receivables and other current assets		54			70
Prepayments		(288	)		(128	)
Accounts payable		18			(50	)
Pensions and retiree benefits obligations		713			578
Pensions and retiree benefits contributions		(821	)		(579	)
Accrued taxes		(80	)		76
Accrued interest		46			57
Superfund and environmental remediation costs (net)		7			—
Deferred charges, noncurrent assets and other regulatory assets		183			92
Deferred credits and other regulatory liabilities		83			158
Other liabilities		16			10
NET CASH FLOWS FROM OPERATING ACTIVITIES		1,638			2,161
INVESTING ACTIVITIES
Utility construction expenditures		(1,450	)		(1,404	)
Cost of removal less salvage		(118	)		(123	)
Non-utility construction expenditures		(68	)		(57	)
Acquisition of Alpaugh solar energy projects		(286	)		—
Proceeds from grants related to renewable energy investments		27			4
Net investment in Pilesgrove solar project and other		28			(31	)
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(1,867	)		(1,611	)
FINANCING ACTIVITIES
Net proceeds from short-term debt		340			—
Preferred stock redemption		(239	)		—
Retirement of long-term debt		(304	)		(3	)
Issuance of long-term debt		400			—
Issuance of common shares for stock plans, net of repurchases		(16	)		41
Debt issuance costs		(4	)		—
Common stock dividends		(524	)		(519	)
Preferred stock dividends		(3	)		(9	)
NET CASH FLOWS USED IN FINANCING ACTIVITIES		(350	)		(490	)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD		(579	)		60
BALANCE AT BEGINNING OF PERIOD		648			338
BALANCE AT END OF PERIOD		$      69			$    398
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash paid/(refunded) during the period for:
Interest		$    379			$    371
Income taxes		$      46			$  (132	)

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

8

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2012		December 31, 2011
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments		$       69		$     648
Accounts receivable – customers, less allowance for uncollectible accounts of $85 and $87 in 2012 and 2011, respectively		1,319		1,123
Accrued unbilled revenue		451		474
Other receivables, less allowance for uncollectible accounts of $10 in 2012 and 2011		216		303
Fuel oil, gas in storage, materials and supplies, at average cost		355		356
Prepayments		433		145
Deferred tax assets – current		113		266
Regulatory assets		77		164
Other current assets		207		159
TOTAL CURRENT ASSETS		3,240		3,638
INVESTMENTS		462		455
UTILITY PLANT, AT ORIGINAL COST
Electric		22,019		21,114
Gas		5,009		4,734
Steam		2,034		1,983
General		2,253		1,944
TOTAL		31,315		29,775
Less: Accumulated depreciation		6,388		6,051
Net		24,927		23,724
Construction work in progress		898		1,241
NET UTILITY PLANT		25,825		24,965
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $66 and $59 in 2012 and 2011, respectively		99		89
Construction work in progress		400		39
NET PLANT		26,324		25,093
OTHER NONCURRENT ASSETS
Goodwill		429		429
Intangible assets, less accumulated amortization of $3 in 2012 and 2011		3		3
Regulatory assets		8,897		9,337
Other deferred charges and noncurrent assets		278		259
TOTAL OTHER NONCURRENT ASSETS		9,607		10,028
TOTAL ASSETS		$39,633		$39,214

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

9

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2012		December 31, 2011
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year		$     930		$     530
Notes payable		340		—
Accounts payable		968		955
Customer deposits		308		303
Accrued taxes		108		188
Accrued interest		206		160
Accrued wages		88		91
Fair value of derivative liabilities		56		169
Regulatory liabilities		231		118
Other current liabilities		489		473
TOTAL CURRENT LIABILITIES		3,724		2,987
NONCURRENT LIABILITIES
Obligations under capital leases		2		2
Provision for injuries and damages		145		181
Pensions and retiree benefits		4,039		4,835
Superfund and other environmental costs		537		489
Asset retirement obligations		149		145
Fair value of derivative liabilities		34		48
Other noncurrent liabilities		124		131
TOTAL NONCURRENT LIABILITIES		5,030		5,831
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits		8,026		7,563
Regulatory liabilities		1,102		977
Other deferred credits		70		64
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES		9,198		8,604
LONG-TERM DEBT		9,839		10,143
SHAREHOLDERS’ EQUITY
Common shareholders’ equity (See Statement of Common Shareholders’ Equity)		11,842		11,436
Preferred stock of subsidiary		—		213
TOTAL SHAREHOLDERS’ EQUITY		11,842		11,649
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY		$39,633		$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
Net income for common stock									165															165
Common stock dividends									(175	)														(175	)
Issuance of common shares – dividend reinvestment and employee stock plans		603,513					32					(182,942	)		5									37
Common stock repurchases												178,942			(9	)								(9	)
Other comprehensive income																					2			2
BALANCE AS OF JUNE 30, 2011		292,875,896			$32		$4,977		$7,346			23,206,700			$(1,005	)		$(64	)		$(35	)		$11,251
Net income for common stock									383															383
Common stock dividends									(176	)														(176	)
Issuance of common shares – dividend reinvestment and employee stock plans		8,000					6					(554,356	)		19									25
Common stock repurchases												546,356			(31	)								(31	)
Other comprehensive income																					2			2
BALANCE AS OF SEPTEMBER 30, 2011		292,883,896			$32		$4,983		$7,553			23,198,700			$(1,017	)		$(64	)		$(33	)		$11,454
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
Net income for common stock									214															214
Common stock dividends									(178	)														(178	)
Issuance of common shares for stock plans, net of repurchases		1,700					—					(1,700	)		—			(1	)					(1	)
Other comprehensive loss																					(1	)		(1	)
BALANCE AS OF JUNE 30, 2012		292,882,996			$32		$4,991		$7,704			23,199,600			$(1,035	)		$(61	)		$(52	)		$11,579
Net income for common stock									440															440
Common stock dividends									(177	)														(177	)
Issuance of common shares for stock plans, net of repurchases		(11,100	)				—					11,100			(2	)		—						(2	)
Other comprehensive income																					2			2
BALANCE AS OF September 30, 2012		292,871,896			$32		$4,991		$7,967			23,210,700			$(1,037	)		$(61	)		$(50	)		$11,842

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

11

Consolidated Edison Company of New York, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2012			2011			2012			2011
	(Millions of Dollars)
OPERATING REVENUES
Electric		$2,611			$2,644			$6,307			$6,378
Gas		189			197			1,017			1,156
Steam		68			76			414			508
TOTAL OPERATING REVENUES		2,868			2,917			7,738			8,042
OPERATING EXPENSES
Purchased power		604			736			1,554			1,840
Fuel		59			73			213			317
Gas purchased for resale		45			57			264			412
Other operations and maintenance		725			678			2,065			1,906
Depreciation and amortization		225			209			664			618
Taxes, other than income taxes		456			462			1,300			1,330
TOTAL OPERATING EXPENSES		2,114			2,215			6,060			6,423
OPERATING INCOME		754			702			1,678			1,619
OTHER INCOME (DEDUCTIONS)
Investment and other income		2			(6	)		6			3
Allowance for equity funds used during construction		—			1			2			6
Other deductions		(2	)		(3	)		(10	)		(12	)
TOTAL OTHER INCOME (DEDUCTIONS)		—			(8	)		(2	)		(3	)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE		754			694			1,676			1,616
INTEREST EXPENSE
Interest on long-term debt		130			130			395			393
Other interest		8			4			19			13
Allowance for borrowed funds used during construction		—			(1	)		(1	)		(3	)
NET INTEREST EXPENSE		138			133			413			403
INCOME BEFORE INCOME TAX EXPENSE		616			561			1,263			1,213
INCOME TAX EXPENSE		227			205			436			425
NET INCOME		389			356			827			788
Preferred stock dividend requirements		—			(3	)		(3	)		(9	)
NET INCOME FOR COMMON STOCK		$389			$353			$824			$779

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 September 30,				For the Nine Month Ended September 30,
	2012		2011		2012			2011
	(Millions of Dollars)
NET INCOME		$389		$356		$827			$788
OTHER COMPREHENSIVE LOSS, NET OF TAXES
Pension plan liability adjustments, net of $(1) taxes in 2012		—		—		(2	)		—
TOTAL OTHER COMPREHENSIVE LOSS, NET OF TAXES		—		—		(2	)		—
COMPREHENSIVE INCOME		$389		$356		$825			$788

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

13

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Nine Months Ended September 30,
	2012			2011
	(Millions of Dollars)
OPERATING ACTIVITIES
Net income		$    827			$    788
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization		664			618
Deferred income taxes		220			309
Rate case amortization and accruals		32			38
Common equity component of allowance for funds used during construction		(2	)		(6	)
Other non-cash items (net)		84			60
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers, less allowance for uncollectibles		(197	)		3
Materials and supplies, including fuel oil and gas in storage		12			2
Other receivables and other current assets		(41	)		243
Prepayments		(308	)		(303	)
Accounts payable		50			(45	)
Pensions and retiree obligations		639			527
Pensions and retiree contributions		(761	)		(532	)
Accrued taxes		40			(7	)
Accrued interest		46			46
Superfund and environmental remediation costs (net)		7			—
Deferred charges, deferred derivative losses, noncurrent assets and other regulatory assets		84			33
Deferred credits and other regulatory liabilities		88			167
Other liabilities		(21	)		19
NET CASH FLOWS FROM OPERATING ACTIVITIES		1,463			1,960
INVESTING ACTIVITIES
Utility construction expenditures		(1,368	)		(1,332	)
Cost of removal less salvage		(115	)		(118	)
NET CASH FLOWS USED IN INVESTING ACTIVITIES		(1,483	)		(1,450	)
FINANCING ACTIVITIES
Net proceeds from short-term debt		332			—
Preferred stock redemption		(239	)		—
Retirement of long-term debt		(300	)
Issuance of long-term debt		400			—
Debt issuance costs		(4	)		—
Dividend to parent		(512	)		(509	)
Preferred stock dividends		(3	)		(9	)
NET CASH FLOWS USED IN FINANCING ACTIVITIES		(326	)		(518	)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD		(346	)		(8	)
BALANCE AT BEGINNING OF PERIOD		372			78
BALANCE AT END OF PERIOD		$26			$70
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash paid/(refunded) during the period for:
Interest		$    344			$    336
Income taxes		$      50			$   (103	)

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

14

Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

	September 30, 2012		December 31, 2011
	(Millions of Dollars)
ASSETS
CURRENT ASSETS
Cash and temporary cash investments		$       26		$     372
Accounts receivable – customers, less allowance for uncollectible accounts of $79 in 2012 and 2011		1,174		977
Other receivables, less allowance for uncollectible accounts of $9 in 2012 and 2011		103		102
Accrued unbilled revenue		347		366
Accounts receivable from affiliated companies		82		54
Fuel oil, gas in storage, materials and supplies, at average cost		296		308
Prepayments		393		85
Regulatory assets		62		140
Deferred tax assets – current		62		157
Other current assets		114		100
TOTAL CURRENT ASSETS		2,659		2,661
INVESTMENTS		203		177
UTILITY PLANT AT ORIGINAL COST
Electric		20,728		19,886
Gas		4,448		4,200
Steam		2,034		1,983
General		2,081		1,785
TOTAL		29,291		27,854
Less: Accumulated depreciation		5,834		5,523
Net		23,457		22,331
Construction work in progress		850		1,165
NET UTILITY PLANT		24,307		23,496
NON-UTILITY PROPERTY
Non-utility property, less accumulated depreciation of $25 and $24 in 2012 and 2011, respectively		4		6
NET PLANT		24,311		23,502
OTHER NONCURRENT ASSETS
Regulatory assets		8,285		8,661
Other deferred charges and noncurrent assets		241		217
TOTAL OTHER NONCURRENT ASSETS		8,526		8,878
TOTAL ASSETS		$35,699		$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)

	September 30, 2012		December 31, 2011
	(Millions of Dollars)
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year		$     925		$     525
Notes payable		332		—
Accounts payable		772		774
Accounts payable to affiliated companies		22		16
Customer deposits		295		290
Accrued taxes		33		32
Accrued taxes to affiliated companies		165		126
Accrued interest		179		133
Accrued wages		83		81
Fair value of derivative liabilities		30		98
Regulatory liabilities		199		79
Other current liabilities		400		396
TOTAL CURRENT LIABILITIES		3,435		2,550
NONCURRENT LIABILITIES
Obligations under capital leases		2		2
Provision for injuries and damages		138		173
Pensions and retiree benefits		3,627		4,337
Superfund and other environmental costs		423		373
Asset retirement obligations		148		145
Fair value of derivative liabilities		12		24
Other noncurrent liabilities		116		120
TOTAL NONCURRENT LIABILITIES		4,466		5,174
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits		7,301		6,921
Regulatory liabilities		978		861
Other deferred credits		67		61
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES		8,346		7,843
LONG-TERM DEBT		8,920		9,220
SHAREHOLDER’S EQUITY
Common shareholder’s equity (See Statement of Common Shareholder’s Equity)		10,532		10,218
Preferred stock		—		213
TOTAL SHAREHOLDER’S EQUITY		10,532		10,431
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY		$35,699		$35,218

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

16

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
Net income								160												160
Common stock dividend to parent								(170	)											(170	)
Cumulative preferred dividends								(3	)											(3	)
Other comprehensive income																	—			—
BALANCE AS OF JUNE 30, 2011		235,488,094		$589		$4,234		$6,217			$(962	)		$(64	)		$  (6	)		$10,008
Net income								356												356
Common stock dividend to parent								(169	)											(169	)
Cumulative preferred dividends								(3	)											(3	)
Other comprehensive income																	—			—
BALANCE AS OF SEPTEMBER 30, 2011		235,488,094		$589		$4,234		$6,401			$(962	)		$(64	)		$  (6	)		$10,192
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
Net income								163												163
Common stock dividend to parent								(171	)											(171	)
Other comprehensive loss																	(2	)		(2	)
BALANCE AS OF JUNE 30, 2012		235,488,094		$589		$4,234		$6,523			$(962	)		$(60	)		$(10	)		$10,314
Net income								389												389
Common stock dividend to parent								(171	)											(171	)
Other comprehensive loss																	—			—
BALANCE AS OF SEPTEMBER 30, 2012		235,488,094		$589		$4,234		$6,741			$(962	)		$(60	)		$(10	)		$10,532

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

17

NOTES TO THE FINANCIAL STATEMENTS (UNAUDITED)

General

These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Con Edison’s other utility subsidiary, Orange and Rockland Utilities, Inc. (O&R), 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 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2012 and June 30, 2012. 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.

18

Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

For the three and nine months ended September 30, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2012		2011
Net income for common stock		$   440		$   383		$   931		$   860
Weighted average common shares outstanding – basic		292.9		292.9		292.9		292.5
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.7		1.7		1.7
Adjusted weighted average common shares outstanding – diluted		294.6		294.6		294.6		294.2
Net income for common stock per common share – basic		$  1.50		$  1.31		$  3.18		$  2.94
Net income for common stock per common share – diluted		$  1.49		$  1.30		$  3.16		$  2.92

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 the NYSPSC approved in June 2012, 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 is being 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 on a cumulative basis at the end of rate year three;

• continuation of a revenue decoupling mechanism;

19

• 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, property taxes and certain other expenses are reconciled to amounts for those expenses 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 September 30, 2012, the company had collected an estimated $1,031 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. These estimated potential overcharges related to transactions that involved certain employees who were arrested and a contractor that performed work for the company. The company expects that the NYSPSC’s consultant will be reporting an estimate of potential overcharges with respect to a substantial portion of the company’s construction expenditures from January 2000 to January 2009, including expenditures for transactions that did not involve the arrested employees and contractor. The NYSPSC consultant’s estimate is expected to be materially higher than its $21 million provisional assessment. The NYSPSC’s consultant is developing its estimate based on its review of a selection of the construction expenditures and its extrapolation of the results of its review (which the company is disputing). The NYSPSC’s consultant is expected to continue to review the company’s expenditures. At September 30, 2012, the company had a $15 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.

20

Regulatory Assets and Liabilities

Regulatory assets and liabilities at September 30, 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		$5,211		$5,852		$4,972		$5,554
Future income tax		1,888		1,798		1,810		1,724
Environmental remediation costs		722		681		607		564
Pension and other post retirement benefits deferrals		205		198		174		157
Revenue taxes		177		163		171		158
Surcharge for New York State assessment		135		90		125		82
Deferred storm costs		120		128		78		80
Net electric deferrals		107		121		107		121
Deferred derivative losses – long-term		47		60		25		44
O&R transition bond charges		40		44		—		—
Preferred stock redemption		29		—		29		—
Workers’ compensation		19		23		19		23
Property tax reconciliation		15		13		—		—
Recoverable energy costs – long-term		1		14		1		14
Other		181		152		167		140
Regulatory assets – long-term		8,897		9,337		8,285		8,661
Deferred derivative losses – current		75		164		62		140
Recoverable energy costs – current		2		—		—		—
Regulatory assets – current		77		164		62		140
Total Regulatory Assets		$8,974		$9,501		$8,347		$8,801
Regulatory liabilities
Allowance for cost of removal less salvage		$   488		$   448		$   407		$   372
Property tax reconciliation		137		35		137		35
Net unbilled revenue deferrals		121		104		121		104
World Trade Center settlement proceeds		62		62		62		62
Long-term interest rate reconciliation		54		30		54		30
Carrying charges on transmission and distribution net plant		36		38		16		14
Expenditure prudence proceeding		15		11		15		11
Gas line losses		14		21		14		21
Energy efficiency programs		5		22		5		20
Other		170		206		147		192
Regulatory liabilities – long-term		1,102		977		978		861
Revenue decoupling mechanism		107		66		103		66
Electric surcharge offset		60		—		60		—
Refundable energy costs – current		58		51		30		12
Deferred derivative gains – current		6		1		6		1
Regulatory liabilities – current		231		118		199		79
Total Regulatory Liabilities		$1,333		$1,095		$1,177		$   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). In November 2012, CECONY purchased $225 million of its tax-exempt debt that was subject to mandatory tender.

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

(Millions of Dollars)	September 30, 2012				December 31, 2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison		$10,769		$13,197		$10,673		$12,744
CECONY		$  9,845		$12,001		$  9,745		$11,593

21

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,561 million and $636 million of the fair value of long-term debt at September 30, 2012 are classified as Level 2 and Level 3, respectively. For CECONY, $11,365 million and $636 million of the fair value of long-term debt at September 30, 2012 are classified as Level 2 and Level 3, respectively (see Note K). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

Note D — Short-Term Borrowing

At September 30, 2012, Con Edison had $340 million of commercial paper outstanding, $332 million of which was outstanding under CECONY’s program. The weighted average interest rate was 0.3 percent for each of Con Edison and CECONY. The Companies have not borrowed under their October 2011 credit agreement. Con Edison had $207 million of letters of credit outstanding under the credit agreement (including $192 million for CECONY).

Note E — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic benefit costs for the three and nine months ended September 30, 2012 and 2011 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses		$   59			$   48			$   55			$   45
Interest cost on projected benefit obligation		137			140			128			131
Expected return on plan assets		(176	)		(184	)		(168	)		(174	)
Amortization of net actuarial loss		177			133			168			126
Amortization of prior service costs		2			2			2			—
NET PERIODIC BENEFIT COST		$ 199			$ 139			$ 185			$ 128
Cost capitalized		(64	)		(45	)		(60	)		(42	)
Reconciliation to rate level		—			(11	)		(1	)		(11	)
Cost charged to operating expenses		$ 135			$   83			$ 124			$   75

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses		$ 177			$ 142			$ 165			$ 133
Interest cost on projected benefit obligation		410			420			385			393
Expected return on plan assets		(528	)		(550	)		(503	)		(524	)
Amortization of net actuarial loss		531			397			503			376
Amortization of prior service costs		6			6			4			4
NET PERIODIC BENEFIT COST		$ 596			$ 415			$ 554			$ 382
Amortization of regulatory asset		1			1			1			1
TOTAL PERIODIC BENEFIT COST		$ 597			$ 416			$ 555			$ 383
Cost capitalized		(200	)		(141	)		(186	)		(131	)
Reconciliation to rate level		(37	)		(68	)		(36	)		(70	)
Cost charged to operating expenses		$ 360			$ 207			$ 333			$ 182

Expected Contributions

The Companies made contributions to the pension plan during 2012 of $775 million (of which $721 million was contributed by CECONY). The Companies’ policy is to fund their pension plan’s accounting cost to the extent tax deductible. During the first nine months of 2012, CECONY also funded $12 million for the non-qualified supplemental plan.

22

Note F — Other Postretirement Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic postretirement benefit costs for the three and nine months ended September 30, 2012 and 2011 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost		$   6			$   7			$   5			$   5
Interest cost on accumulated other postretirement benefit obligation		18			20			16			18
Expected return on plan assets		(21	)		(22	)		(19	)		(21	)
Amortization of net actuarial loss		24			22			22			20
Amortization of prior service cost		(5	)		(3	)		(4	)		(3	)
Amortization of transition obligation		—			1			—			1
NET PERIODIC POSTRETIREMENT BENEFIT COST		$ 22			$ 25			$ 20			$ 20
Cost capitalized		(8	)		(9	)		(7	)		(7	)
Reconciliation to rate level		3			3			3			3
Cost charged to operating expenses		$ 17			$ 19			$ 16			$ 16

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost		$ 20			$ 19			$ 15			$ 15
Interest cost on accumulated other postretirement benefit obligation		55			62			48			54
Expected return on plan assets		(64	)		(66	)		(56	)		(59	)
Amortization of net actuarial loss		73			66			65			60
Amortization of prior service cost		(16	)		(7	)		(13	)		(9	)
Amortization of transition obligation		1			3			1			3
NET PERIODIC POSTRETIREMENT BENEFIT COST		$ 69			$ 77			$ 60			$ 64
Cost capitalized		(24	)		(27	)		(20	)		(22	)
Reconciliation to rate level		15			12			12			10
Cost charged to operating expenses		$ 60			$ 62			$ 52			$ 52

Expected Contributions

Con Edison expects to make a contribution of $83 million, including $71 million for CECONY, to the other postretirement benefit plans in 2012. During the first nine months of 2012, Con Edison contributed $34 million to the other postretirement benefit plans (of which $28 million was contributed by CECONY).

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.”

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

The accrued liabilities and regulatory assets related to Superfund Sites at September 30, 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		$352		$307
Other Superfund Sites		71		67		71		66
Total		$537		$489		$423		$373
Regulatory assets		$722		$681		$607		$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 and nine months ended September 30, 2012 and 2011, were as follows:

	For the Three Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred		$3		$9		$1		$9
Insurance recoveries received		—		—		—		—

	For the Nine Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred		$18		$24		$15		$22
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

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thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. In 2010, CECONY estimated that its aggregate undiscounted potential liability for these suits and additional suits that may be brought over the next 15 years is $10 million. The estimate was based upon a combination of modeling, historical data analysis and risk factor assessment. Actual experience may be materially different. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. Under its current rate agreements, CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims. The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at September 30, 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		$94		$98		$89		$93
Regulatory assets – workers’ compensation		$19		$23		$19		$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 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

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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 $(73) million at September 30, 2012 and $(55) million at December 31, 2011 and is comprised of a $228 million gross investment less $301 million of deferred tax liabilities at September 30, 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. Oral argument on the appeal is scheduled to be held in November 2012.

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 2011, 2010, 2009 and 2008, the IRS has disallowed $35 million, $40 million, $41 million and $42 million, respectively, of net tax deductions taken with respect to both of the LILO transactions. When these audit level disallowances become appealable, Con Edison intends to file an appeal of the disallowances.

Con Edison believes that its LILO transactions have been correctly reported, and has not recorded any reserve with respect to the disallowance of tax losses, or related interest, in connection with its LILO transactions. Con Edison’s estimated tax savings, reflected in its financial statements, from the two LILO transactions through September 30, 2012, in the aggregate, was $248 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 $122 million net of tax at September 30, 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.

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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 $823 million and $760 million at September 30, 2012 and December 31, 2011, respectively.

A summary, by type and term, of Con Edison’s total guarantees at September 30, 2012 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions		$696		$2		$66		$764
Intra-company guarantees		15		—		1		16
Other guarantees		38		5		—		43
TOTAL		$749		$7		$67		$823

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;

• $11 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 September 30, 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 September 30,
	Operating revenues					Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012		2011			2012			2011			2012		2011		2012			2011
CECONY
Electric		$2,611		$2,644			$    4			$    3			$179		$166		$812			$758
Gas		189		197			1			1			31		28		(21	)		(23	)
Steam		68		76			20			20			15		15		(37	)		(33	)
Consolidation adjustments		—		—			(25	)		(24	)		—		—		—			—
Total CECONY		$2,868		$2,917			$  —			$  —			$225		$209		$754			$702
O&R
Electric		$   199		$   217			$  —			$  —			$  10		$    9		$  50			$  44
Gas		27		24			—			—			3		3		(6	)		(6	)
Total O&R		$   226		$   241			$  —			$  —			$  13		$  12		$  44			$  38
Competitive energy businesses		$   344		$   472			$    2			$    3			$    2		$    1		$  53			$  16
Other*		—		(1	)		(2	)		(3	)		—		—		—			—
Total Con Edison		$3,438		$3,629			$  —			$  —			$240		$222		$851			$756

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

	For the Nine Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012			2011			2012			2011			2012		2011		2012			2011
CECONY
Electric		$6,307			$6,378			$  11			$    9			$527		$489		$1,383			$1,326
Gas		1,017			1,156			4			4			89		82		255			212
Steam		414			508			58			59			48		47		40			81
Consolidation adjustments		—			—			(73	)		(72	)		—		—		—			—
Total CECONY		$7,738			$8,042			$  —			$  —			$664		$618		$1,678			$1,619
O&R
Electric		$   457			$   507			$  —			$  —			$  28		$  26		$     74			$     69
Gas		144			153			—			—			11		10		26			22
Total O&R		$   601			$   660			$  —			$  —			$  39		$  36		$   100			$     91
Competitive energy businesses		$   954			$1,286			$    6			$    9			$    6		$    5		$   111			$     75
Other*		(6	)		(16	)		(6	)		(9	)		—		—		(3	)		(4	)
Total Con Edison		$9,287			$9,972			$  —			$  —			$709		$659		$1,886			$1,781

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

In July 2012, Con Edison Development purchased a company that is developing 70 MW (AC) of solar energy projects in Alpaugh, California (Alpaugh). Electricity generated by the projects is to be purchased by Pacific Gas and Electric Company pursuant to long-term power purchase agreements (PPA). Alpaugh was purchased for $288 million, including contingent consideration of $2 million, of which $284 million has been allocated to construction work in progress and $4 million to deposits relating to the PPA and interconnection agreements. The total cost to acquire and construct these projects is estimated to be $350 million.

In October 2012, Con Edison Development purchased two companies that are developing 40 MW (AC) of solar energy projects in Tulare and Kings County, California. Electricity generated by the projects is to be purchased by Pacific Gas and Electric Company pursuant to long-term PPAs. The projects were purchased for approximately $51 million, of which $39 million has been allocated to construction work in progress and $12 million to deposits relating to the PPA and interconnection agreements. The total cost to acquire and construct these projects is estimated to be $200 million.

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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 September 30, 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		$(92	)		$(249	)		$(48	)		$(144	)
Impact of netting of cash collateral		59			110			33			46
Fair value of net derivative assets/(liabilities) – net		$(33	)		$(139	)		$(15	)		$  (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 September 30, 2012, Con Edison and CECONY had $118 million and $13 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $44 million with investment-grade counterparties, $25 million with commodity exchange brokers, $47 million with independent system operators and $2 million with non-rated counterparties. CECONY’s net credit exposure consisted of $3 million with investment-grade counterparties and $10 million with commodity exchange brokers.

Economic Hedges

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

The fair values of the Companies’ commodity derivatives at September 30, 2012 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets		$   91			$ 30
Long-term	Other deferred charges and non-current assets		19			10
Total derivative assets			$ 110			$ 40
Impact of netting			(59	)		(13	)
Net derivative assets			$   51			$ 27

Derivative Liabilities
Current	Fair value of derivative liabilities	$ 149		$ 60
Long-term	Fair value of derivative liabilities	53		28
Total derivative liabilities		$ 202		$ 88
Impact of netting		(118	)	(46	)
Net derivative liabilities		$   84		$ 42

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

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The 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
Derivative Assets
Current	Other current assets		$ 139			$  16
Long-term	Other deferred charges and non-current assets		26			14
Total derivative assets			$ 165			$  30
Impact of netting			(95	)		(6	)
Net derivative assets			$   70			$  24
Derivative Liabilities
Current	Fair value of derivative liabilities		$ 331			$127
Long-term	Fair value of derivative liabilities		83			48
Total derivative liabilities			$ 414			$175
Impact of netting			(205	)		(53	)
Net derivative liabilities			$ 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 tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2012:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended September 30, 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		$   5			$   5
Long-term	Deferred derivative gains		1			1
Total deferred gains/(losses)			$   6			$   6
Current	Deferred derivative losses		$ 51			$ 42
Current	Recoverable energy costs		(60	)		(52	)
Long-term	Deferred derivative losses		22			20
Total deferred gains/(losses)			$ 13			$ 10
Net deferred gains/(losses)			$ 19			$ 16
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$   9	(b)		$  —
	Gas purchased for resale		—			—
	Non-utility revenue		1	(b)		—
Total pre-tax gain/(loss) recognized in income			$ 10			$  —

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

(b) For the three months ended September 30, 2012, Con Edison recorded in purchased power expense an unrealized pre-tax gain/(loss) of $30 million.

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Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 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		$     5			$     5
Long-term	Deferred derivative gains		1			1
Total deferred gains/(losses)			$     6			$     6
Current	Deferred derivative losses		$   89			$   78
Current	Recoverable energy costs		(187	)		(164	)
Long-term	Deferred derivative losses		13			19
Total deferred gains/(losses)			$  (85	)		$  (67	)
Net deferred gains/(losses)			$  (79	)		$  (61	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$  (49	)(b)		$    —
	Gas purchased for resale		(2	)		—
	Non-utility revenue		(11	)(b)		—
Total pre-tax gain/(loss) recognized in income			$  (62	)		$    —

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

(b) For the nine months ended September 30, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $75 million, respectively.

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

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

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

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

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Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains		$    —			$    —
Long-term	Regulatory liabilities		3			3
Total deferred gains/(losses)			$     3			$     3
Current	Deferred derivative losses		$   80			$   60
Current	Recoverable energy costs		(177	)		(134	)
Long-term	Regulatory assets		38			27
Total deferred gains/(losses)			$  (59	)		$  (47	)
Net deferred gains/(losses)			$  (56	)		$  (44	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$   81	(b)		$    —
	Gas purchased for resale		17			—
	Non-utility revenue		22	(b)		—
Total pre-tax gain/(loss) recognized in income			$ 120			$    —

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

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

As of September 30, 2012, Con Edison had 1,289 contracts, including 628 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)		MW-Months (b)		Number of Contracts (a)		dths (b)		Total Number of Contracts (a)
Con Edison		576		12,807,613		78		10,019		635		86,541,700		1,289
CECONY		113		3,271,000		—		—		515		81,080,000		628

(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 the clearing 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.

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The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position and collateral posted at September 30, 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		$62			$41
Collateral posted		$14			$  9
Additional collateral (b) (downgrade one level from current ratings (c))		$ —			$ —
Additional collateral (b) (downgrade to below investment grade from current ratings (c))		$85	(d)		$45	(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 September 30, 2012, would have amounted to an estimated $25 million for Con Edison. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

(b) 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 September 30, 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 $27 million.

Interest Rate Swap

O&R has an interest rate swap pursuant to which it pays a fixed-rate of 6.09 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at September 30, 2012 was an unrealized loss of $6 million, which has been included in Con Edison’s consolidated balance sheet as a noncurrent liability/fair value of derivative liabilities and a regulatory asset. The increase in the fair value of the swap for the three and nine months ended September 30, 2012 was $1 million and $2 million, respectively. In the event O&R’s credit rating was downgraded to BBB- or lower by S&P or Baa3 or lower by Moody’s, the swap counterparty could elect to terminate the agreement and, if it did so, the parties would then be required to settle the transaction.

Note 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.

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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 September 30, 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			$  2		$  48			$  16			$   47			$ 12			$  (46	)		$  (3	)		$   51			$  27
Transfer in (5) (6)		—			—		24			—			—			—			—			—			24			—
Transfer out (5) (6)		—			—		—			—			(24	)		—			—			—			(24	)		—
Commodity Total		$    2			$  2		$  72			$  16			$   23			$ 12			$  (46	)		$  (3	)		$ 51			$  27
Other assets		103			96		—			1			105			95			—			—			208			192
Transfer in (5) (6)		—			—		105			95			—			—			—			—			105			95
Transfer out (5) (6)		—			—		—			—			(105	)		(95	)		—			—			(105	)		(95	)
Other assets (3)		$103			$96		$105			$  96			$    —			$  —			$    —			$  —			$ 208			$192
Total		$105			$98		$177			$112			$   23			$ 12			$  (46	)		$  (3	)		$ 259			$219
Derivative liabilities:
Commodity		$    4			$  1		$114			$  68			$   71			$   9			$(105	)		$(36	)		$   84			$  42
Transfer in (5) (6)		7			7		50			12			3			3			—			—			60			22
Transfer out (5) (6)		(2	)		—		(10	)		(10	)		(48	)		(12	)		—			—			(60	)		(22	)
Commodity Total (1)		$9			$  8		$154			$  70			$   26			$  —			$(105	)		$(36	)		$   84			$  42
Interest rate contract		—			—		(2	)		—			8			—			—			—			6			—
Transfer in (5) (6)		—			—		8			—			—			—			—			—			8			—
Transfer out (5) (6)		—			—		—			—			(8	)		—			—			—			(8	)		—
Interest rate contract (2)		$   —			$ —		$    6			$ —			$    —			$  —			$    —			$  —			$     6			$   —
Total		$    9			$  8		$160			$70			$   26			$  —			$(105	)		$(36	)		$   90			$  42

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(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 between Level 3 and Levels 1 and 2 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall. Other assets and interest rate contract were transferred as of March 31, 2012.

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.

	Fair Value of Level 3 at September 30, 2012 (Millions of Dollars)			Valuation Techniques	Unobservable Inputs	Range
Con Edison—Commodity
Electricity Swaps	$	(9	)	Discounted Cash Flow	Forward prices (1)	$22-$64 per MWH
Electricity Wholesale Contract		4		Discounted Cash Flow	Auction prices (2) New Jersey solar renewable energy credit (SREC) (2)	$29-$52 per MWH $85 per SREC
Standard Offer Capacity Agreements		(12	)	Discounted Cash Flow	Forward capacity prices (1) Forward price escalator (1) Present value factor (1)	$166 MW per day 0%-3% 1.66%
Transmission Congestion Contracts / Financial Transmission Rights		14		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (2) Discount to adjust auction prices for historical monthly realized settlements (2) Historical line loss factor (1)	17.5%-38% (3)%-26.5% 8%
Total Con Edison—Commodity	$	(3	)
CECONY—Commodity
Transmission Congestion Contracts	$	12		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (2) Discount to adjust auction prices for historical monthly realized settlements (2)	17.5%-38% (3)%- 26.5%

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

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

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2012 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30, 2012
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 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 September 30, 2012
Con Edison
Derivatives:
Commodity		$(61	)		$(15	)		$19		$7		$—		$—		$25		$22		$  (3	)
CECONY
Derivatives:
Commodity		$(10	)		$  (9	)		$  8		$7		$—		$—		$  5		$11		$ 12

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	For the Nine Months Ended September 30, 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 September 30, 2012
Con Edison
Derivatives:
Commodity		$(62)		$(97)		$11		$18		$—		$—		$106		$     21			$ (3)
Interest rate contract		(8)		(1)		—		—		—		—		1		8(2	)		—
Other assets (1)		99		3		3		—		—		—		—		(105	)(2)		—
Total		$  29		$(95)		$14		$18		$—		$—		$107		$   (76)			$ (3)
CECONY
Derivatives:
Commodity		$  (7)		$(25)		$  8		$15		$—		$—		$  12		$    9(2	)		$ 12
Other assets (1)		90		3		2		—		—		—		—		(95	)(2)		—
Total		$  83		$(22)		$10		$15		$—		$—		$  12		$   (86)			$ 12

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

(2) Other assets and interest rate contract were transferred as of March 31, 2012.

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

	For the Three Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity		$ (25	)		$(37	)		$ 9			$8		$—		$—		$14		$24		$    (7	)
Interest rate contract		(10	)		(1	)		1			—		—		—		1		—		(9	)
Other assets (1)		106			(3	)		(3	)		—		—		—		—		—		100
Total		$  71			$(41	)		$ 7			$8		$—		$—		$15		$24		$   84
CECONY
Derivatives:
Commodity		$   —			$  (8	)		$ 1			$8		$—		$—		$  3		$  9		$   13
Other assets (1)		96			(3	)		(2	)		—		—		—		—		—		91
Total		$  96			$(11	)		$(1	)		$8		$—		$—		$  3		$  9		$ 104

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

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	For the Nine Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity		$ (88	)		$(59	)		$54			$22		$—		$—		$35			$29		$    (7	)
Interest rate contract		(10	)		(3	)		1			—		—		—		3			—		(9	)
Other assets (1)		101			—			(1	)		—		—		—		—			—		100
Total		$    3			$(62	)		$54			$22		$—		$—		$38			$29		$   84
CECONY
Derivatives:
Commodity		$ (26	)		$(11	)		$22			$18		$—		$—		$ (4	)		$14		$   13
Other assets (1)		92			—			(1	)		—		—		—		—			—		91
Total		$  66			$(11	)		$21			$18		$—		$—		$ (4	)		$14		$ 104

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

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

For the competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($2 million loss and $10 million loss) and purchased power costs ($2 million gain and $12 million loss) on the consolidated income statement for the three months ended September 30, 2012 and 2011, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($11 million loss and $35 million loss), and purchased power costs ($42 million loss and $6 million gain) on the consolidated income statement for the nine months ended September 30, 2012 and 2011, respectively. The change in fair value relating to Level 3 commodity derivative assets held at September 30, 2012 and 2011 is included in non-utility revenues ($2 million loss and $10 million loss), and purchased power costs ($16 million gain and $5 million loss) on the consolidated income statement for the three months ended September 30, 2012 and 2011, respectively. For the nine months ended September 30, 2012 and 2011, the change in fair value relating to Level 3 commodity derivative assets and liabilities included in non-utility revenues ($11 million loss and $35 million loss), and purchased power costs ($40 million gain and $31 million gain) on the consolidated income statement, 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 September 30, 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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Note L — Hurricane Sandy

In late October 2012, Hurricane Sandy caused extensive damage to the Utilities’ electric distribution system and interrupted service to approximately 950,000 CECONY customers and approximately 250,000 O&R customers. Hurricane Sandy also damaged CECONY’s steam system and interrupted service to many of its steam customers. To restore service to their customers and repair their energy systems, the Utilities are incurring substantial operating costs and making substantial capital expenditures, the amount of which the Utilities are unable to estimate at this time. The Utilities’ rate plans provide for operating costs and capital expenditures under different provisions. The Utilities expect that most of their operating expenses attributable to Hurricane Sandy will be deferred for recovery as a regulatory asset under their electric rate plans. The Utilities’ capital expenditures, up to specified levels, are reflected in rates under their rate plans. In addition CECONY’s rate plans provide that it may request in its next base rate filings to recover additional capital expenditures (provided the company can justify the need for and reasonableness of, and its inability to reasonably avoid, such additional capital expenditures). Under its New York electric rate plan and subject to certain limitations, O&R defers as a regulatory asset the revenue requirement impact of the amount by which actual average net utility plant is different than the average net utility plant reflected in rates. Under the New York rate plans, the Utilities also may petition the NYSPSC for authorization to defer extraordinary expenditures not otherwise addressed in their rate plans. The Utilities’ New York electric rate plans include provisions for revenue decoupling, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved. The provisions of the Utilities’ New York electric plans that impose penalties for operating performance provide for exceptions for major storms and catastrophic events beyond the control of the companies, including natural disasters such as hurricanes and floods. The Utilities expect the NYSPSC to investigate the preparation and performance of New York utilities in connection with Hurricane Sandy.

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

This combined management’s discussion and analysis of financial condition and results of operations (MD&A) relates to the consolidated financial statements (the Third Quarter Financial Statements) included in this report of two separate registrants: Consolidated Edison, Inc. (Con Edison) and Consolidated Edison Company of New York, Inc. (CECONY). 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 Third Quarter Financial Statements and the notes thereto and the MD&A in Item 7 of the Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2011 (File Nos. 1-14514 and 1-1217, the Form 10-K) and the MD&A in Part 1, Item 2 of the Companies’ combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2012 and June 30, 2012 (File Nos. 1-14514 and 1-1217).

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

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

CECONY’s principal business operations are its regulated electric, gas and steam delivery businesses. O&R’s principal business operations are its regulated electric and gas delivery businesses. The competitive energy businesses sell electricity to 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.

In the late October 2012, Hurricane Sandy caused extensive damage to the Utilities’ electric distribution system and interrupted service to approximately 950,000 CECONY customers and approximately 250,000 O&R customers. See Note L to the Third Quarter Financial Statements.

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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.

In June 2012, the company increased its forecast of average annual growth of the peak gas demand in its service area over the next five years at design conditions from approximately 3.5 percent to 4.3 percent, reflecting, among other things, oil to gas conversions anticipated to result from changes to New York City regulations that will phase out the use of certain types of heating oil and the relative prices of oil and natural gas.

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.

Collective Bargaining Agreement

In July 2012, CECONY reached a four-year collective bargaining agreement covering approximately 8,000 employees (which was ratified in August 2012 by the employees) ending a 26-day work stoppage involving those employees. During the work stoppage, the company operated its electric, gas and steam businesses with approximately 5,500 employees and additional resources.

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 September 30, 2012, Con Edison’s equity investment in its competitive energy businesses was $514 million and their assets amounted to $1,021 million. For information about purchases of solar energy companies during 2012, see “Liquidity and Capital Resources – Capital Requirements and Resources,” below.

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

	Three Months Ended September 30, 2012								Nine Months Ended September 30, 2012								At September 30, 2012
(Millions of Dollars, except percentages)	Operating Revenues				Net Income for Common Stock				Operating Revenues				Net Income for Common Stock				Assets
CECONY		$2,868	83%			$389	88%			$7,738	83%			$824	88%			$35,699	90%
O&R		226	7%			24	6%			601	7%			54	6%			2,474	6%
Total Utilities		3,094	90%			413	94%			8,339	90%			878	94%			38,173	96%
Con Edison Solutions (a)		321	9%			28	6%			874	9%			60	6%			304	1%
Con Edison Energy (a)		20	1%			1	—%			69	1%			—	—%			65	—%
Con Edison Development		5	—%			2	1%			17	—%			5	1%			676	2%
Other (b)		(2)	—%			(4)	(1)%			(12)	—%			(12)	(1)%			415	1%
Total Con Edison		$3,438	100	%		$440	100	%		$9,287	100	%		$931	100	%		$39,633	100	%

(a) Net income from the competitive energy businesses for the three and nine months ended September 30, 2012 includes $17 million and $35 million, respectively, of net after-tax mark-to-market gains/(losses) (Con Edison Solutions, $17 million and $37 million and Con Edison Energy, $0 million and $(2) million)).

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

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Con Edison’s net income for common stock for the three months ended September 30, 2012 was $440 million or $1.50 a share ($1.49 on a diluted basis) compared with $383 million or $1.31 a share ($1.30 on a diluted basis) for the three months ended September 30, 2011. Net income for common stock for the nine months ended September 30, 2012 was $931 million or $3.18 a share ($3.16 on a diluted basis) compared with earnings of $860 million or $2.94 a share ($2.92 on a diluted basis) for the nine months ended September 30, 2011. See “Results of Operations – Summary,” below. For segment financial information, see Note I to the Third Quarter Financial Statements and “Results of Operations,” below.

Results of Operations — Summary

Net income for common stock for the three and nine months ended September 30, 2012 and 2011 was as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
(millions of dollars)	2012			2011		2012			2011
CECONY		$389			$353		$824			$779
O&R		24			20		54			44
Competitive energy businesses (a)		31			10		65			46
Other (b)		(4	)		—		(12	)		(9	)
Con Edison		$440			$383		$931			$860

(a) Includes $17 million and $(7) million of net after-tax mark-to-market gains/(losses) for the three months ended September 30, 2012 and 2011, respectively. Includes $35 million and $14 million of net after-tax mark-to-market gains for the nine months ended September 30, 2012 and 2011, respectively.

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

The Companies’ results of operations for the three and nine months ended September 30, 2012, as compared with the 2011 periods, 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. The results of operations include the operating results of the competitive energy businesses, including net mark-to-market effects.

Operations and maintenance expenses were higher in the 2012 periods due to pension costs and the support and maintenance of company underground facilities to accommodate municipal projects. Depreciation was higher in the 2012 periods reflecting the impact of higher utility plant balances.

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

	Three Months Variation						Nine Months Variation
	Earnings per Share			Net Income (millions of dollars)			Earnings per Share			Net Income (millions of dollars)
CECONY
Rate plans, primarily to recover increases in certain costs		$0.24			$71			$0.65			$192
Weather impact on steam revenues		—			—			(0.10	)		(28	)
Operations and maintenance expenses		(0.10	)		(31	)		(0.33	)		(98	)
Depreciation		(0.03	)		(10	)		(0.09	)		(27	)
Other		0.01			6			0.02			6
Total CECONY		0.12			36			0.15			45
O&R		0.01			4			0.04			11
Competitive energy businesses (a)		0.08			21			0.06			19
Other, including parent company expenses		(0.02	)		(4	)		(0.01	)		(4	)
Total variations		$0.19			$57			$0.24			$71

(a) These variations reflect after-tax net mark-to-market gains/(losses) of $17 million or $0.06 a share and $(7) million or $(0.02) a share for the three months ended September 30, 2012 and 2011, respectively, and after-tax net mark-to-market gains of $35 million or $0.12 a share and $14 million or $0.05 a share for the nine months ended September 30, 2012 and 2011, respectively.

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

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Liquidity and Capital Resources

The Companies’ liquidity reflects cash flows from operating, investing and financing activities, as shown on their respective consolidated statement of cash flows and as discussed below. Changes in the Companies’ cash and temporary cash investments resulting from operating, investing and financing activities for the nine months ended September 30, 2012 and 2011 are summarized as follows:

Con Edison

	Con Edison									CECONY
(millions of dollars)	2012			2011			Variance			2012			2011			Variance
Operating activities		$ 1,638			$ 2,161			$(523	)		$ 1,463			$ 1,960			$(497	)
Investing activities		(1,867	)		(1,611	)		(256	)		(1,483	)		(1,450	)		(33	)
Financing activities		(350	)		(490	)		140			(326	)		(518	)		192
Net change		(579	)		60			(639	)		(346	)		(8	)		(338	)
Balance at beginning of period		648			338			310			372			78			294
Balance at end of period		$      69			$    398			$(329	)		$      26			$      70			$  (44	)

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 and deferred income tax expense. 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. In addition, the Companies’ cash flows from operating activities reflect the timing of the deduction for income tax purposes of their construction expenditures.

Net cash flows from operating activities for the nine months ended September 30, 2012 for Con Edison and CECONY were $523 million and $497 million lower, respectively, compared with the 2011 period. The decrease in net cash flows reflects primarily the increased pension contributions in 2012 ($243 million for Con Edison and $231 million for CECONY). The Companies contributed $787 million and $544 million (of which $733 million and $502 million was contributed by CECONY) to the pension plan during 2012 and 2011, respectively. The decrease in net cash flows is also due to higher estimated income tax payments, net of refunds received, in 2012 ($178 million for Con Edison and $153 million for CECONY) and lower cash flows associated with collateral paid to brokers and counterparties in the 2012 period ($53 million for Con Edison and $50 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 Third Quarter Financial Statements.

Cash Flows Used in Investing Activities

Net cash flows used in investing activities for Con Edison and CECONY were $256 million and

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$33 million higher for the nine months ended September 30, 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 capital expenditures for Alpaugh and other solar energy projects (see “Capital Requirements and Resources,” below), return of investment resulting from the receipt of government grant proceeds at the Pilesgrove solar project and proceeds from grants related to other renewable investments.

Cash Flows from Financing Activities

Net cash flows from financing activities for Con Edison and CECONY were $140 million and $192 million higher, respectively, in the nine months ended September 30, 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 Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value). In July 2012, CECONY redeemed at maturity $300 million 5.625 percent 10-year debentures. The Companies had no issuances of long-term debt in 2011.

Cash flows from financing activities of the Companies also reflect commercial paper issuances (included on the consolidated balance sheets as “Notes payable”). The commercial paper amounts outstanding at September 30, 2012 and 2011 and the average daily balances for the nine months ended September 30, 2012 and 2011 for Con Edison and CECONY were as follows:

	2012						2011
(millions of dollars, except Weighted Average Yield)	Outstanding at September 30			Daily average			Outstanding at September 30			Daily average
Con Edison		$340			$116			$—			$110
CECONY		$332			$112			$—			$110
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 September 30, 2012, compared with December 31, 2011.

	Con Edison			CECONY
(millions of dollars)	2012 vs. 2011 Variance			2012 vs. 2011 Variance
Assets
Regulatory asset – Unrecognized pension and other postretirement costs		$(641	)		$(582	)
Non-utility plant – Construction work in progress		361			—
Prepayments		288			308
Liabilities
Pensions and retiree benefits		(796	)		(710	)
Deferred income taxes and investment tax credits		463			380

Regulatory Asset for Unrecognized Pension and Other Postretirement Costs and Noncurrent Liability for Pensions 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 Third Quarter Financial Statements.

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Non-Utility Plant – Construction Work in Progress

The increase in non-utility plant – construction work in progress for Con Edison reflects the Alpaugh and other solar energy projects. See Note I to the Third Quarter Financial Statements.

Prepayments

The increase in prepayments for Con Edison and CECONY reflects the portion allocable to the 2012 fourth quarter of CECONY’s July 2012 payment of its New York City semi-annual property taxes.

Deferred Income Taxes and Investment Tax Credits

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

Capital Requirements and Resources

As of September 30, 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 below and in Note C to the Third Quarter Financial Statements.

In July 2012, Con Edison Development purchased a company that is developing 70 MW (AC) of solar energy projects in Alpaugh, California. In October 2012, Con Edison Development purchased two companies that are developing 40 MW (AC) of solar energy projects in Tulare and Kings County, California. Electricity generated by the projects is to be purchased by Pacific Gas and Electric Company pursuant to long-term power purchase agreements. See Note I to the Third Quarter Financial Statements.

Con Edison has increased its estimate of capital expenditures in 2012 by its competitive energy businesses from $119 million to approximately $500 million and in 2013 from $86 million to approximately $240 million to reflect the costs to purchase the solar energy companies and complete the projects. The acquisitions of the solar energy companies were funded at the closing with available cash balances and commercial paper issuances. Con Edison is evaluating long-term financing for the projects. Con Edison expects to receive investment tax credits or grants for the projects.

For each of the Companies, the ratio of earnings to fixed charges (Securities and Exchange Commission basis) for the nine months ended September 30, 2012 and 2011 and the twelve months ended December 31, 2011 was:

	Ratio of Earnings to Fixed Charges
	For the Nine Months Ended September 30, 2012		For the Twelve Months Ended December 31, 2011		For the Nine Months Ended September 30, 2011
Con Edison		3.9		3.6		3.8
CECONY		3.9		3.8		3.9

For each of the Companies, the common equity ratio at September 30, 2012 and December 31, 2011 was:

	Common Equity Ratio (Percent of total capitalization)
	September 30, 2012		December 31, 2011
Con Edison		54.6		52.5
CECONY		54.1		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. The company is preparing to

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file a new rate plan with the NYSPSC in November 2012. A new rate plan is expected to be effective in October 2013.

CECONY’s current gas and steam rate agreements cover the three-year period ending September 30, 2013. The company is preparing to file new gas and steam rate plans with the NYSPSC in November 2012. New gas and steam rate plans are expected to be effective in October 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 (which was adopted by the NYSPSC in June 2012) with respect to its rates for electric service rendered in New York, see Note B to the Third Quarter Financial Statements.

Financial and Commodity Market Risks

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

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 September 30, 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 tax-exempt (and under the gas rate plan, taxable) long-term debt 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 Swap” in Note J to the Third Quarter Financial Statements.

Commodity Price Risk

Con Edison’s commodity price risk relates primarily to the purchase and sale of electricity, gas and related derivative instruments. The Utilities and Con Edison’s competitive energy businesses apply risk management strategies to mitigate their related exposures. See Note J to the Third Quarter Financial Statements.

Con Edison estimates that, as of September 30, 2012, a 10 percent decline in market prices would result in a decline in fair value of $54 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $43 million is for CECONY and $11 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

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and commodity contracts, assuming a one-day holding period, for the nine months ended September 30, 2012 and the year ended December 31, 2011, respectively, was as follows:

95% Confidence Level, One-Day Holding Period	September 30, 2012		December 31, 2011
	(millions of dollars)
Average for the period		$1		$1
High		1		1
Low		—		—

Credit Risk

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

Investment Risk

The Companies’ investment risk relates to the investment of plan assets for their pension and other postretirement benefit plans. The Companies’ current investment policy for pension plan assets includes investment targets of 60 percent equities and 40 percent fixed income and other securities. At September 30, 2012, the pension plan investments consisted of 62 percent equity and 38 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 Third Quarter Financial Statements.

Results of Operations

See “Results of Operations – Summary,” above.

Results of operations reflect, among other things, the Companies’ accounting policies and rate plans that limit the rates the Utilities can charge their customers. Under the revenue decoupling mechanisms currently applicable to CECONY’s electric and gas businesses and O&R’s electric and gas businesses in New York, the Utilities’ delivery revenues generally will not be affected by changes in delivery volumes from levels assumed when rates were approved. Delivery revenues for CECONY’s steam business and O&R’s businesses in New Jersey and Pennsylvania are affected by changes in delivery volumes resulting from weather, economic conditions and other factors. See Note B to the Third 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 and nine months ended September 30, 2012 and 2011 follows. For additional business segment financial information, see Note I to the Third Quarter Financial Statements.

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Three Months Ended September 30, 2012 Compared with Three Months Ended September 30, 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		$  (49	)		(1.7	)%		$(15	)		(6.2	)%		$(127	)		(27.0	)%		$(191	)		(5.3	)%
Purchased power		(132	)		(17.9	)		(25	)		(26.3	)		(152	)		(37.3	)		(309	)		(24.9	)
Fuel		(14	)		(19.2	)		—			—			—			—			(14	)		(19.2	)
Gas purchased for resale		(12	)		(21.1	)		2			22.2			(7	)		Large			(17	)		(23.3	)
Operating revenues less purchased power, fuel and gas purchased for resale (net revenues)		109			5.3			8			5.8			32			57.1			149			6.6
Operations and maintenance		47			6.9			1			1.4			(5	)		(14.7	)		43			5.5
Depreciation and amortization		16			7.7			1			8.3			1			Large			18			8.1
Taxes, other than income taxes		(6	)		(1.3	)		—			—			(1	)		(20.0	)		(7	)		(1.4	)
Operating income		52			7.4			6			15.8			37			Large			95			12.6
Other income less deductions		8			Large			(1	)		Large			(4	)		(66.7	)		3			Large
Net interest expense		5			3.8			—			—			3			60.0			8			5.6
Income before income tax expense		55			9.8			5			15.2			30			Large			90			14.7
Income tax expense		22			10.7			1			7.7			13			Large			36			16.0
Net income		33			9.3			4			20.0			17			Large			54			14.0
Preferred stock dividend requirements		(3	)		Large			—			—			—			—			(3	)		Large
Net income for common stock		$   36			10.2	%		$   4			20.0	%		$   17			Large			$   57			14.9	%

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

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

CECONY

	Three Months Ended September 30, 2012										Three Months Ended September 30, 2011
(millions of dollars)	Electric		Gas			Steam			2012 Total		Electric		Gas			Steam			2011 Total		2012-2011 Variation
Operating revenues		$2,611		$189			$ 68			$2,868		$2,644		$197			$ 76			$2,917		$  (49	)
Purchased power		597		—			7			604		726		—			10			736		(132	)
Fuel		42		—			17			59		51		—			22			73		(14	)
Gas purchased for resale		—		45			—			45		—		57			—			57		(12	)
Net revenues		1,972		144			44			2,160		1,867		140			44			2,051		109
Operations and maintenance		601		81			43			725		559		82			37			678		47
Depreciation and amortization		179		31			15			225		166		28			15			209		16
Taxes, other than income taxes		380		53			23			456		384		53			25			462		(6	)
Operating income		$    812		$ (21	)		$(37	)		$    754		$    758		$ (23	)		$(33	)		$    702		$    52

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Electric

CECONY’s results of electric operations for the three months ended September 30, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues		$2,611		$2,644		$  (33	)
Purchased power		597		726		(129	)
Fuel		42		51		(9	)
Net revenues		1,972		1,867		105
Operations and maintenance		601		559		42
Depreciation and amortization		179		166		13
Taxes, other than income taxes		380		384		(4	)
Electric operating income		$   812		$   758		$   54

CECONY’s electric sales and deliveries, excluding off-system sales, for the three months ended September 30, 2012 compared with the 2011 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012			September 30, 2011			Variation			Percent Variation
Residential/Religious (a)		3,735		3,808		(73	)		(1.9	)%	$	959		$	999		$	(40	)		(4.0	)%
Commercial/Industrial		2,908		3,165		(257	)		(8.1	)		616			705			(89	)		(12.6	)
Retail access customers		7,874		7,151		723			10.1			894			766			128			16.7
NYPA, Municipal Agency and other sales		2,957		3,103		(146	)		(4.7	)		202			192			10			5.2
Other operating revenues		—		—		—			—			(60	)		(18	)		(42	)		Large
Total		17,474		17,227		247			1.4	%	$	2,611		$	2,644		$	(33	)		(1.2	)%

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

CECONY’s electric operating revenues decreased $33 million in the three months ended September 30, 2012 compared with the 2011 period due primarily to lower purchased power ($129 million) and fuel costs ($9 million), offset in part by higher revenues from the electric rate plan ($112 million). CECONY’s revenues from electric sales are subject to a revenue decoupling mechanism, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved. Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the revenue decoupling mechanism and other provisions of the company’s rate plan.

Electric delivery volumes in CECONY’s service area increased 1.4 percent in the three months ended September 30, 2012 compared with the 2011 period. After adjusting for variations, principally weather and billing days, electric delivery volumes in CECONY’s service area increased 2.0 percent in the three months ended September 30, 2012 compared with the 2011 period reflecting higher average use per customer.

CECONY’s electric purchased power costs decreased $129 million in the three months ended September 30, 2012 compared with the 2011 period due to a decrease in purchased volumes ($88 million) and unit costs ($41 million). Electric fuel costs decreased $9 million in the three months ended September 30, 2012 compared with the 2011 period due to lower unit costs ($16 million), offset by higher sendout volumes from the company’s electric generating facilities ($7 million).

CECONY’s electric operating income increased $54 million in the three months ended September 30, 2012 compared with the 2011 period. The increase reflects primarily higher net revenues ($105 million, due

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primarily to the electric rate plan) and lower taxes, other than income taxes ($4 million, principally property taxes), offset by higher operations and maintenance costs ($42 million) and higher depreciation and amortization ($13 million). The increase in operations and maintenance costs of $42 million is due primarily to higher pension expense ($40 million) and higher support and maintenance of company underground facilities to accommodate municipal projects ($2 million).

Gas

CECONY’s results of gas operations for the three months ended September 30, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	September 30, 2012			September 30, 2011			Variation
Operating revenues	$	189		$	197		$	(8	)
Gas purchased for resale		45			57			(12	)
Net revenues		144			140			4
Operations and maintenance		81			82			(1	)
Depreciation and amortization		31			28			3
Taxes, other than income taxes		53			53			—
Gas operating income	$	(21	)	$	(23	)	$	2

CECONY’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, 2012 compared with the 2011 period were:

	Thousands of dths Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012		September 30, 2011			Variation			Percent Variation
Residential		2,971		2,984		(13	)		(0.4	)%	$	75	$	82		$	(7	)		(8.5	)%
General		3,415		3,453		(38	)		(1.1	)		38		45			(7	)		(15.6	)
Firm transportation		6,752		6,751		1			—			47		45			2			4.4
Total firm sales and transportation		13,138		13,188		(50	)		(0.4	)		160		172			(12	)		(7.0	)
Interruptible sales (a)		1,217		2,020		(803	)		(39.8	)		—		9			(9	)		Large
NYPA		13,716		13,401		315			2.4			1		1			—			—
Generation plants		29,644		26,501		3,143			11.9			10		9			1			11.1
Other		4,791		4,425		366			8.3			9		7			2			28.6
Other operating revenues		—		—		—			—			9		(1	)		10			Large
Total		62,506		59,535		2,971			5.0	%	$	189	$	197		$	(8	)		(4.1	)%

(a) Includes 2,801 mdths and 1,138 mdths for the three months ended September 30, 2012 and 2011, respectively, which are also reflected in firm transportation and other.

CECONY’s gas operating revenues decreased $8 million in the three months ended September 30, 2012 compared with the 2011 period due primarily to a decrease in gas purchased for resale costs ($12 million). CECONY’s revenues from gas sales are subject to a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. Other gas operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan.

CECONY’s sales and transportation volumes for firm customers decreased 0.4 percent in the three months ended September 30, 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 decreased 1.0 percent in the three months ended September 30, 2012.

CECONY’s purchased gas cost decreased $12 million in the three months ended September 30, 2012 compared with the 2011 period due to lower unit costs ($18 million), offset by higher sendout volumes ($6 million).

CECONY’s gas operating income increased $2 million in the three months ended September 30, 2012 compared with the 2011 period. The increase reflects primarily higher net revenues ($4 million) and lower operations and maintenance costs ($1 million), offset by higher depreciation ($3 million).

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Steam

CECONY’s results of steam operations for the three months ended September 30, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	September 30, 2012			September 30, 2011			Variation
Operating revenues	$	68		$	76		$	(8	)
Purchased power		7			10			(3	)
Fuel		17			22			(5	)
Net revenues		44			44			—
Operations and maintenance		43			37			6
Depreciation and amortization		15			15			—
Taxes, other than income taxes		23			25			(2	)
Steam operating income	$	(37	)	$	(33	)	$	(4	)

CECONY’s steam sales and deliveries for the three months ended September 30, 2012 compared with the 2011 period were:

	Millions of Pounds Delivered									Revenues in Millions
	Three Months Ended									Three Months Ended
Description	September 30, 2012		September 30, 2011		Variation		Percent Variation			September 30, 2012			September 30, 2011			Variation			Percent Variation
General		15		15		—		—	%	$	2		$	2		$	—			—	%
Apartment house		816		799		17		2.1			17			17			—			—
Annual power		3,487		3,440		47		1.4			59			58			1			1.7
Other operating revenues		—		—		—		—			(10	)		(1	)		(9	)		Large
Total		4,318		4,254		64		1.5	%	$	68		$	76		$	(8	)		(10.5	)%

CECONY’s steam operating revenues decreased $8 million in the three months ended September 30, 2012 compared with the 2011 period due primarily to lower fuel ($5 million) and purchased power costs ($3 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 increased 1.5 percent in the three months ended September 30, 2012 compared with the 2011 period. After adjusting for variations, principally weather and billing days, steam sales and deliveries increased 1.9 percent in the three months ended September 30, 2012, reflecting higher average normalized use per customer.

CECONY’s steam fuel costs decreased $5 million in the three months ended September 30, 2012 compared with the 2011 period due to lower unit costs ($5 million). Steam purchased power costs decreased $3 million in the three months ended September 30, 2012 compared with the 2011 period due to a decrease in unit costs ($3 million).

Steam operating income decreased $4 million in the three months ended September 30, 2012 compared with the 2011 period. The decrease reflects primarily higher operations and maintenance costs ($6 million, due primarily to higher pension expense ($8 million)), offset by lower taxes, other than income taxes ($2 million, principally property taxes).

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Net Interest Expense

Net interest expense increased $5 million in the three months ended September 30, 2012 compared with the 2011 period due primarily to the issuance by CECONY in March 2012 of $400 million of 4.20 percent 30-year debentures.

O&R

	Three Months Ended September 30, 2012							Three Months Ended September 30, 2011
(millions of dollars)	Electric		Gas			2012 Total		Electric		Gas			2011 Total		2012-2011 Variation
Operating revenues	$	199	$	27		$	226	$	217	$	24		$	241	$	(15	)
Purchased power		70		—			70		95		—			95		(25	)
Gas purchased for resale		—		11			11		—		9			9		2
Net revenues		129		16			145		122		15			137		8
Operations and maintenance		57		15			72		56		15			71		1
Depreciation and amortization		10		3			13		9		3			12		1
Taxes, other than income taxes		12		4			16		13		3			16		—
Operating income	$	50	$	(6	)	$	44	$	44	$	(6	)	$	38	$	6

Electric

O&R’s results of electric operations for the three months ended September 30, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues	$	199	$	217	$	(18	)
Purchased power		70		95		(25	)
Net revenues		129		122		7
Operations and maintenance		57		56		1
Depreciation and amortization		10		9		1
Taxes, other than income taxes		12		13		(1	)
Electric operating income	$	50	$	44	$	6

O&R’s electric sales and deliveries, excluding off-system sales, for the three months ended September 30, 2012 compared with the 2011 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012		September 30, 2011			Variation			Percent Variation
Residential/Religious (a)		550		578		(28	)		(4.8	)%	$	97	$	113		$	(16	)		(14.2	)%
Commercial/Industrial		247		315		(68	)		(21.6	)		38		49			(11	)		(22.4	)
Retail access customers		885		789		96			12.2			59		53			6			11.3
Public authorities		32		33		(1	)		(3.0	)		3		3			—			—
Other operating revenues		—		—		—			—			2		(1	)		3			Large
Total		1,714		1,715		(1	)		(0.1	)%	$	199	$	217		$	(18	)		(8.3	)%

(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 $18 million in the three months ended September 30, 2012 compared with the 2011 period due primarily to lower purchased power costs ($25 million), offset in part by higher revenues from the New York rate plan ($3 million). O&R’s New York electric delivery revenues

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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 Second Quarter Financial Statements.

Electric delivery volumes in O&R’s service area decreased 0.1 percent in the three months ended September 30, 2012 compared with the 2011 period. After adjusting for weather and other variations, electric delivery volumes in O&R’s service area increased 2.7 percent in the three months ended September 30, 2012 compared with the 2011 period.

Electric operating income increased $6 million in the three months ended September 30, 2012 compared with the 2011 period. The increase reflects primarily higher net revenues ($7 million) and lower taxes, other than income taxes ($1 million), offset by higher operations and maintenance costs ($1 million), and depreciation and amortization ($1 million).

Gas

O&R’s results of gas operations for the three months ended September 30, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	September 30, 2012			September 30, 2011			Variation
Operating revenues	$	27		$	24		$	3
Gas purchased for resale		11			9			2
Net revenues		16			15			1
Operations and maintenance		15			15			—
Depreciation and amortization		3			3			—
Taxes, other than income taxes		4			3			1
Gas operating income	$	(6	)	$	(6	)	$	—

O&R’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, 2012 compared with the 2011 period were:

	Thousands of dths Delivered										Revenues in Millions
	Three Months Ended										Three Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012		September 30, 2011		Variation		Percent Variation
Residential		433		380		53			13.9	%	$	8	$	8	$	—		—	%
General		103		77		26			33.8			1		1		—		—
Firm transportation		910		714		196			27.5			9		8		1		12.5
Total firm sales and transportation		1,446		1,171		275			23.5			18		17		1		5.9
Interruptible sales		995		907		88			9.7			1		1		—		—
Generation plants		444		359		85			23.7			—		—		—		—
Other		65		77		(12	)		(15.6	)		—		—		—		—
Other gas revenues		—		—		—			—			8		6		2		33.3
Total		2,950		2,514		436			17.3	%	$	27	$	24	$	3		12.5	%

O&R’s gas operating revenues increased $3 million in the three months ended September 30, 2012 compared with the 2011 period due primarily to the increase in gas purchased for resale in 2012 ($2 million). O&R’s New York revenues from gas sales are subject to a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

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Sales and transportation volumes for firm customers increased 23.5 percent in the three months ended September 30, 2012 compared with the 2011 period. After adjusting for weather and other variations, total firm sales and transportation volumes decreased 5.3 percent in the three months ended September 30, 2012 compared with the 2011 period.

Gas operating income was the same in the three months ended September 30, 2012 compared with the 2011 period.

Competitive Energy Businesses

The competitive energy businesses’ results of operations for the three months ended September 30, 2012 compared with the 2011 period is as follows:

	Three Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues	$	344	$	472	$	(128	)
Purchased power		256		408		(152	)
Gas purchased for resale		—		6		(6	)
Net revenues		88		58		30
Operations and maintenance		29		35		(6	)
Depreciation and amortization		2		1		1
Taxes, other than income taxes		4		6		(2	)
Operating income	$	53	$	16	$	37

The competitive energy businesses’ operating revenues decreased $128 million in the three months ended September 30, 2012 compared with the 2011 period, due primarily to lower electric retail and wholesale revenues. Electric wholesale revenues decreased $47 million in the three months ended September 30, 2012 as compared with the 2011 period, due to lower unit prices ($27 million) and sales volumes ($20 million). Electric retail revenues decreased $81 million, due to lower unit prices ($44 million) and sales volume ($37 million). Net mark-to-market values increased $41 million in the three months ended September 30, 2012 as compared with the 2011 period, of which $32 million in gains are reflected in purchased power costs and $9 million in gains are reflected in revenues. Other revenues decreased $9 million in the three months ended September 30, 2012 as compared with the 2011 period due primarily to lower other wholesale revenue.

Purchased power costs decreased $152 million in the three months ended September 30, 2012 compared with the 2011 period, due primarily to lower volumes ($69 million), lower unit prices ($51 million) and changes in mark-to-market values ($32 million). Operating income increased $37 million in the three months ended September 30, 2012 compared with the 2011 period due primarily to net mark-to-market effects ($41 million).

Other

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

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Nine Months Ended September 30, 2012 Compared with Nine Months Ended September 30, 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	$	(304	)		(3.8	)%	$	(59	)		(8.9	)%	$	(322	)		(25.4	)%	$	(685	)		(6.9	)%
Purchased power		(286	)		(15.5	)		(68	)		(31.2	)		(330	)		(31.0	)		(684	)		(21.9	)
Fuel		(104	)		(32.8	)		—			—			—			—			(104	)		(32.8	)
Gas purchased for resale		(148	)		(35.9	)		(14	)		(22.6	)		(15	)		(88.2	)		(177	)		(36.0	)
Operating revenues less purchased power, fuel and gas purchased for resale (net revenues)		234			4.3			23			6.1			23			12.3			280			4.6
Operations and maintenance		159			8.3			7			3.3			(14	)		(14.7	)		152			6.9
Depreciation and amortization		46			7.4			3			8.3			1			20.0			50			7.6
Taxes, other than income taxes		(30	)		(2.3	)		4			9.8			(1	)		(6.3	)		(27	)		(1.9	)
Operating income		59			3.6			9			9.9			37			52.1			105			5.9
Other income less deductions		1			33.3			(3	)		Large			(7	)		(53.8	)		(9	)		(69.2	)
Net interest expense		10			2.5			(4	)		(15.4	)		1			5.3			7			1.6
Income before income tax expense		50			4.1			10			14.7			29			44.6			89			6.6
Income tax expense		11			2.6			—			—			13			46.4			24			5.0
Net income		39			4.9			10			22.7			16			43.2			65			7.5
Preferred stock dividend requirements		(6	)		(66.7	)		—			—			—			—			(6	)		(66.7	)
Net income for common stock	$	45			5.8	%	$	10			22.7	%	$	16			43.2	%	$	71			8.3	%

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

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

CECONY

	Nine Months Ended September 30, 2012								Nine Months Ended September 30, 2011
(millions of dollars)	Electric		Gas		Steam		2012 Total		Electric		Gas		Steam		2011 Total		2012-2011 Variation
Operating revenues	$	6,307	$	1,017	$	414	$	7,738	$	6,378	$	1,156	$	508	$	8,042	$	(304	)
Purchased power		1,527		—		27		1,554		1,799		—		41		1,840		(286	)
Fuel		122		—		91		213		167		—		150		317		(104	)
Gas purchased for resale		—		264		—		264		—		412		—		412		(148	)
Net revenues		4,658		753		296		5,707		4,412		744		317		5,473		234
Operations and maintenance		1,691		242		132		2,065		1,522		275		109		1,906		159
Depreciation and amortization		527		89		48		664		489		82		47		618		46
Taxes, other than income taxes		1,057		167		76		1,300		1,075		175		80		1,330		(30	)
Operating income	$	1,383	$	255	$	40	$	1,678	$	1,326	$	212	$	81	$	1,619	$	59

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Electric

CECONY’s results of electric operations for the nine months ended September 30, 2012 compared with the 2011 period is as follows:

	Nine Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues	$	6,307	$	6,378	$	(71	)
Purchased power		1,527		1,799		(272	)
Fuel		122		167		(45	)
Net revenues		4,658		4,412		246
Operations and maintenance		1,691		1,522		169
Depreciation and amortization		527		489		38
Taxes, other than income taxes		1,057		1,075		(18	)
Electric operating income	$	1,383	$	1,326	$	57

CECONY’s electric sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2012 compared with the 2011 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012		September 30, 2011		Variation			Percent Variation
Residential/Religious (a)		8,393		8,934		(541	)		(6.1	)%	$	2,147	$	2,299	$	(152	)		(6.6	)%
Commercial/Industrial		7,561		8,639		(1,078	)		(12.5	)		1,526		1,823		(297	)		(16.3	)
Retail access customers		19,768		18,339		1,429			7.8			2,117		1,794		323			18.0
NYPA, Municipal Agency and other sales		8,233		8,407		(174	)		(2.1	)		477		448		29			6.5
Other operating revenues		—		—					—			40		14		26			Large
Total		43,955		44,319		(364	)		(0.8	)%	$	6,307	$	6,378	$	(71	)		(1.1	)%

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

CECONY’s electric operating revenues decreased $71 million in the nine months ended September 30, 2012 compared with the 2011 period due primarily to lower purchased power ($272 million) and fuel costs ($45 million) offset in part by higher revenues from the electric rate plan ($270 million). CECONY’s revenues from electric sales are subject to a revenue decoupling mechanism, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved. Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the revenue decoupling mechanism and other provisions of the company’s rate plan.

Electric delivery volumes in CECONY’s service area decreased 0.8 percent in the nine months ended September 30, 2012 compared with the 2011 period. After adjusting for variations, principally weather and billing days, electric delivery volumes in CECONY’s service area increased 0.5 percent in the nine months ended September 30, 2012 compared with the 2011 period reflecting higher average use per customer.

CECONY’s electric purchased power costs decreased $272 million in the nine months ended September 30, 2012 compared with the 2011 period due to a decrease in purchased volumes ($224 million) and unit costs ($48 million). Electric fuel costs decreased $45 million in the nine months ended September 30, 2012 compared with the 2011 period due to lower unit costs ($51 million), offset by higher sendout volumes from the company’s electric generating facilities ($6 million).

CECONY’s electric operating income increased $57 million in the nine months ended September 30, 2012 compared with the 2011 period. The increase reflects primarily higher net revenues ($246 million, due primarily to the electric rate plan) and lower taxes,

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other than income taxes ($18 million, principally property taxes). The higher net revenues were offset by higher operations and maintenance costs ($169 million, due primarily to higher pension expense ($118 million), an increase in surcharges that are collected from customers ($35 million) and higher support and maintenance of company underground facilities to accommodate municipal projects ($11 million)) and higher depreciation and amortization ($38 million).

Gas

CECONY’s results of gas operations for the nine months ended September 30, 2012 compared with the 2011 period is as follows:

	Nine Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues	$	1,017	$	1,156	$	(139	)
Gas purchased for resale		264		412		(148	)
Net revenues		753		744		9
Operations and maintenance		242		275		(33	)
Depreciation and amortization		89		82		7
Taxes, other than income taxes		167		175		(8	)
Gas operating income	$	255	$	212	$	43

CECONY’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2012 compared with the 2011 period were:

	Thousands of dths Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012			September 30, 2011			Variation			Percent Variation
Residential		24,590		30,384		(5,794	)		(19.1	)%	$	450		$	553		$	(103	)		(18.6	)%
General		18,012		20,896		(2,884	)		(13.8	)		211			269			(58	)		(21.6	)
Firm transportation		38,620		41,859		(3,239	)		(7.7	)		284			263			21			8.0
Total firm sales and transportation		81,222		93,139		(11,917	)		(12.8	)		945			1,085			(140	)		(12.9	)
Interruptible sales (a)		4,542		8,278		(3,736	)		(45.1	)		24			65			(41	)		(63.1	)
NYPA		34,285		24,536		9,749			39.7			2			2			—			—
Generation plants		63,161		60,706		2,455			4.0			23			25			(2	)		(8.0	)
Other		17,128		17,245		(117	)		(0.7	)		30			40			(10	)		(25.0	)
Other operating revenues		—		—		—			—			(7	)		(61	)		54			88.5
Total		200,338		203,904		(3,566	)		(1.7	)%	$	1,017		$	1,156		$	(139	)		(12.0	)%

^(a)  Includes 4,613 mdths and 3,214 mdths for the nine months ended September 30, 2012 and 2011, respectively, which are also reflected in firm transportation and other.

CECONY’s gas operating revenues decreased $139 million in the nine months ended September 30, 2012 compared with the 2011 period due primarily to a decrease in gas purchased for resale costs ($148 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 12.8 percent in the nine months ended September 30, 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 0.6 percent in the nine months ended September 30, 2012.

57

CECONY’s purchased gas cost decreased $148 million in the nine months ended September 30, 2012 compared with the 2011 period due to lower unit costs ($111 million) and sendout volumes ($37 million).

CECONY’s gas operating income increased $43 million in the nine months ended September 30, 2012 compared with the 2011 period. The increase reflects primarily lower operations and maintenance costs ($33 million, due primarily to a decrease in the surcharges that are collected from customers ($19 million) and higher support and maintenance of company underground facilities to accommodate municipal projects ($6 million)), lower taxes, other than income taxes ($8 million, principally property taxes and local revenue taxes) and higher net revenues ($9 million), offset by higher depreciation ($7 million).

Steam

CECONY’s results of steam operations for the nine months ended September 30, 2012 compared with the 2011 period is as follows:

	Nine Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues	$	414	$	508	$	(94	)
Purchased power		27		41		(14	)
Fuel		91		150		(59	)
Net revenues		296		317		(21	)
Operations and maintenance		132		109		23
Depreciation and amortization		48		47		1
Taxes, other than income taxes		76		80		(4	)
Steam operating income	$	40	$	81	$	(41	)

CECONY’s steam sales and deliveries for the nine months ended September 30, 2012 compared with the 2011 period were:

	Millions of Pounds Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012			September 30, 2011			Variation			Percent Variation
General		308		422		(114	)		(27.0	)%	$	18		$	22		$	(4	)		(18.2	)%
Apartment house		3,858		4,515		(657	)		(14.6	)		112			131			(19	)		(14.5	)
Annual power		10,999		13,041		(2,042	)		(15.7	)		315			375			(60	)		(16.0	)
Other operating revenues		—		—		—			—			(31	)		(20	)		(11	)		(55.0	)
Total		15,165		17,978		(2,813	)		(15.6	)%	$	414		$	508		$	(94	)		(18.5	)%

CECONY’s steam operating revenues decreased $94 million in the nine months ended September 30, 2012 compared with the 2011 period due primarily to lower fuel ($59 million), the impact of milder weather ($47 million) and lower purchased power costs ($14 million), offset by the net change in rates under the steam rate plan ($29 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 15.6 percent in the nine months ended September 30, 2012 compared with the 2011 period reflecting milder winter weather. After adjusting for variations, principally weather and billing days, steam sales and deliveries decreased 0.8 percent in the nine months ended September 30, 2012, reflecting lower average normalized use per customer.

CECONY’s steam fuel costs decreased $59 million in the nine months ended September 30, 2012 compared with the 2011 period due to lower unit costs ($44 million) and sendout volumes ($15 million). Steam purchased power costs decreased $14 million in the nine months ended September 30, 2012 compared with the 2011 period due to a decrease in unit costs ($38 million) offset by an increase in purchased volumes ($24 million).

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Steam operating income decreased $41 million in the nine months ended September 30, 2012 compared with the 2011 period. The decrease reflects primarily lower net revenues ($21 million), higher operations and maintenance costs ($23 million, due primarily to higher pension expense ($31 million)) and higher depreciation and amortization ($1 million), offset by lower taxes, other than income taxes ($4 million, principally property taxes and local revenue taxes).

Net Interest Expense

Net interest expense increased $10 million in the nine months ended September 30, 2012 compared with the 2011 period due primarily to the issuance by CECONY in March 2012 of $400 million of 4.20 percent 30-year debentures.

Income Taxes

Income taxes increased $11 million in the nine months ended September 30, 2012 compared with the 2011 period reflecting higher income before income tax expense, offset by higher deductions for injuries and damages payments in the 2012 period.

O&R

	Nine Months Ended September 30, 2012				Nine Months Ended September 30, 2011
(millions of dollars)	Electric		Gas		2012 Total		Electric		Gas		2011 Total		2012-2011 Variation
Operating revenues	$	457	$	144	$	601	$	507	$	153	$	660	$	(59	)
Purchased power		150		—		150		218		—		218		(68	)
Gas purchased for resale		—		48		48		—		62		62		(14	)
Net revenues		307		96		403		289		91		380		23
Operations and maintenance		171		48		219		164		48		212		7
Depreciation and amortization		28		11		39		26		10		36		3
Taxes, other than income taxes		34		11		45		30		11		41		4
Operating income	$	74	$	26	$	100	$	69	$	22	$	91	$	9

Electric

O&R’s results of electric operations for the nine months ended September 30, 2012 compared with the 2011 period is as follows:

	Nine Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues	$	457	$	507	$	(50	)
Purchased power		150		218		(68	)
Net revenues		307		289		18
Operations and maintenance		171		164		7
Depreciation and amortization		28		26		2
Taxes, other than income taxes		34		30		4
Electric operating income	$	74	$	69	$	5

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O&R’s electric sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2012 compared with the 2011 period were:

	Millions of kWhs Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012		September 30, 2011			Variation			Percent Variation
Residential/Religious (a)		1,297		1,388		(91	)		(6.6	)%	$	210	$	253		$	(43	)		(17.0	)%
Commercial/Industrial		736		912		(176	)		(19.3	)		94		128			(34	)		(26.6	)
Retail access customers		2,315		2,079		236			11.4			138		121			17			14.0
Public authorities		89		83		6			7.2			7		8			(1	)		(12.5	)
Other operating revenues		—		—		—			—			8		(3	)		11			Large
Total		4,437		4,462		(25	)		(0.6	)%	$	457	$	507		$	(50	)		(9.9	)%

(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 $50 million in the nine months ended September 30, 2012 compared with the 2011 period due primarily to lower purchased power costs ($68 million), offset in part by higher revenues from the New York rate plan ($8 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 Second Quarter Financial Statements.

Electric delivery volumes in O&R’s service area decreased 0.6 percent in the nine months ended September 30, 2012 compared with the 2011 period. After adjusting for weather and other variations, electric delivery volumes in O&R’s service area increased 1.8 percent in the nine months ended September 30, 2012 compared with the 2011 period.

Electric operating income increased $5 million in the nine months ended September 30, 2012 compared with the 2011 period. The increase reflects primarily higher net revenues ($18 million), offset by higher operations and maintenance costs ($7 million, due to higher pension and health care expense), taxes other than income taxes ($4 million, principally property taxes) and higher depreciation and amortization ($2 million).

Gas

O&R’s results of gas operations for the nine months ended September 30, 2012 compared with the 2011 period is as follows:

	Nine Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues	$	144	$	153	$	(9	)
Gas purchased for resale		48		62		(14	)
Net revenues		96		91		5
Operations and maintenance		48		48		—
Depreciation and amortization		11		10		1
Taxes, other than income taxes		11		11		—
Gas operating income	$	26	$	22	$	4

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O&R’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2012 compared with the 2011 period were:

	Thousands of dths Delivered										Revenues in Millions
	Nine Months Ended										Nine Months Ended
Description	September 30, 2012		September 30, 2011		Variation			Percent Variation			September 30, 2012		September 30, 2011		Variation			Percent Variation
Residential		4,114		5,127		(1,013	)		(19.8	)%	$	59	$	76	$	(17	)		(22.4	)%
General		827		1,006		(179	)		(17.8	)		10		13		(3	)		(23.1	)
Firm transportation		6,860		7,672		(812	)		(10.6	)		54		52		2			3.8
Total firm sales and transportation		11,801		13,805		(2,004	)		(14.5	)		123		141		(18	)		(12.8	)
Interruptible sales		3,250		3,213		37			1.2			3		3		—			—
Generation plants		444		1,109		(665	)		(60.0	)		—		—		—			—
Other		506		612		(106	)		(17.3	)		—		—		—			—
Other gas revenues		—		—		—			—			18		9		9			Large
Total		16,001		18,739		(2,738	)		(14.6	)%	$	144	$	153	$	(9	)		(5.9	)%

O&R’s gas operating revenues decreased $9 million in the nine months ended September 30, 2012 compared with the 2011 period due primarily to the decrease in gas purchased for resale in 2012 ($14 million). O&R’s New York revenues from gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

Sales and transportation volumes for firm customers decreased 14.5 percent in the nine months ended September 30, 2012 compared with the 2011 period. After adjusting for weather and other variations, total firm sales and transportation volumes increased 0.6 percent in the nine months ended September 30, 2012 compared with the 2011 period.

Gas operating income increased $4 million in the nine months ended September 30, 2012 compared with the 2011 period. The increase reflects primarily higher net revenues ($5 million), offset by higher depreciation and amortization ($1 million).

Competitive Energy Businesses

The competitive energy businesses’ results of operations for the nine months ended September 30, 2012 compared with the 2011 period is as follows:

	Nine Months Ended
(millions of dollars)	September 30, 2012		September 30, 2011		Variation
Operating revenues	$	954	$	1,286	$	(332	)
Purchased power		736		1,076		(340	)
Gas purchased for resale		2		17		(15	)
Net revenues		216		193		23
Operations and maintenance		85		97		(12	)
Depreciation and amortization		6		5		1
Taxes, other than income taxes		14		16		(2	)
Operating income	$	111	$	75	$	36

The competitive energy businesses’ operating revenues decreased $332 million in the nine months ended September 30, 2012 compared with the 2011 period, due primarily to lower electric retail and wholesale revenues. Electric wholesale revenues decreased $122 million in the nine months ended September 30, 2012 as compared with the 2011 period, due to lower sales volumes ($93 million) and unit prices ($29 million). Electric retail revenues decreased $213 million, due to lower sales volume ($115 million) and unit prices ($98 million). Net mark-to-market values increased $37 million in the nine months ended September 30, 2012

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as compared with the 2011 period, of which $16 million in gains are reflected in purchased power costs and $21 million in gains are reflected in revenues. Other revenues decreased $18 million in the nine months ended September 30, 2012 as compared with the 2011 period due primarily to lower other wholesale revenue ($17 million) and energy services revenue ($16 million), offset by higher solar revenue ($14 million).

Purchased power costs decreased $340 million in the nine months ended September 30, 2012 compared with the 2011 period, due primarily to lower volumes ($175 million), lower unit prices ($149 million) and changes in mark-to-market values ($16 million). Operating income increased $36 million in the nine months ended September 30, 2012 compared with the 2011 due primarily to net mark-to-market effects ($37 million).

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.

The Utilities have undertaken 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 new financial and supply chain enterprise resource planning information systems that the Utilities began to use in July 2012. 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 has materially affected the Companies’ internal control over financial reporting. There was no other 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.

63

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
July 1, 2012 to July 31, 2012		107,165		$62.91		—		—
August 1, 2012 to August 31, 2012		46,777		63.88		—		—
September 1, 2012 to September 30, 2012		49,752		59.66		—		—
Total		203,694		$62.34		—		—

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

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Item 6: Exhibits

CON EDISON

Exhibit 12.1	Statement of computation of Con Edison’s ratio of earnings to fixed charges for the nine-month periods ended September 30, 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 12.2	Statement of computation of CECONY’s ratio of earnings to fixed charges for the nine-month periods ended September 30, 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: November 5, 2012	By	/s/    Robert Hoglund
		Robert Hoglund Senior Vice President, Chief Financial Officer and Duly Authorized Officer

66

EX-12.1

Exhibit 12.1

Consolidated Edison, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Nine Months Ended September 30, 2012			For the Twelve Months Ended December 31, 2011		For the Nine Months Ended September 30, 2011
Earnings
Net Income from Continuing Operations		$   931			$1,051		$   860
Preferred Stock Dividend		3			11		9
(Income) or Loss from Equity Investees		(4	)		—		—
Minority Interest Loss		—			—		—
Income Tax		501			600		477
Pre-Tax Income from Continuing Operations		$1,431			$1,662		$1,346
Add: Fixed Charges*		484			642		483
Add: Distributed Income of Equity Investees		—			—		—
Subtract: Interest Capitalized		—			—		—
Subtract: Pre-Tax Preferred Stock Dividend Requirement		5			19		14
Earnings		$1,910			$2,285		$1,815
* Fixed Charges
Interest on Long-term Debt		$   429			$   562		$   423
Amortization of Debt Discount, Premium and Expense		12			20		14
Interest Capitalized		—			—		—
Other Interest		17			18		15
Interest Component of Rentals		21			23		17
Pre-Tax Preferred Stock Dividend Requirement		5			19		14
Fixed Charges		$   484			$   642		$   483
Ratio of Earnings to Fixed Charges		3.9			3.6		3.8

EX-12.2

Exhibit 12.2

Con Edison Company of New York, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Nine Months Ended September 30, 2012		For the Twelve Months Ended December 31, 2011		For the Nine Months Ended September 30, 2011
Earnings
Net Income for Common		$   824		$   978		$   779
Preferred Stock Dividend		3		11		9
Cumulative Effect of Changes in Accounting Principles		—		—		—
(Income) or Loss from Equity Investees		—		—		—
Minority Interest Loss		—		—		—
Income Tax		436		558		425
Pre-Tax Income from Continuing Operations		$1,263		$1,547		$1,213
Add: Fixed Charges*		434		561		422
Add: Amortization of Capitalized Interest		—		—		—
Add: Distributed Income of Equity Investees		—		—		—
Subtract: Interest Capitalized		—		—		—
Subtract: Pre-Tax Preferred Stock Dividend Requirement		—		—		—
Earnings		$1,697		$2,108		$1,635
* Fixed Charges
Interest on Long-term Debt		$383		$505		$379
Amortization of Debt Discount, Premium and Expense		12		18		14
Interest Capitalized		—		—		—
Other Interest		19		16		13
Interest Component of Rentals		20		22		16
Pre-Tax Preferred Stock Dividend Requirement
Fixed Charges		$   434		$   561		$   422
Ratio of Earnings to Fixed Charges		3.9		3.8		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 September 30, 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: November 5, 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 September 30, 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: November 5, 2012

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

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 September 30, 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: November 5, 2012

/s/ 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 September 30, 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: November 5, 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 September 30, 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: November 5, 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 September 30, 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: November 5, 2012

EX-32.2.1

Exhibit 32.2.1

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

I, Kevin Burke, the Chief Executive Officer of Consolidated Edison Company of New York, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 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: November 5, 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 September 30, 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: November 5, 2012

XML

Pension Benefits - Companies' Net Periodic Benefit Costs (Detail) (Pension Benefits [Member], USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Con Edison [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	$ 59	$ 48	$ 177	$ 142
Interest cost on projected benefit obligation	137	140	410	420
Expected return on plan assets	(176)	(184)	(528)	(550)
Amortization of net actuarial loss	177	133	531	397
Amortization of prior service costs	2	2	6	6
NET PERIODIC BENEFIT COST	199	139	596	415
Amortization of regulatory asset			1	1
TOTAL PERIODIC BENEFIT COST			597	416
Cost capitalized	(64)	(45)	(200)	(141)
Reconciliation to rate level		(11)	(37)	(68)
Cost charged to operating expenses	135	83	360	207
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	55	45	165	133
Interest cost on projected benefit obligation	128	131	385	393
Expected return on plan assets	(168)	(174)	(503)	(524)
Amortization of net actuarial loss	168	126	503	376
Amortization of prior service costs	2		4	4
NET PERIODIC BENEFIT COST	185	128	554	382
Amortization of regulatory asset			1	1
TOTAL PERIODIC BENEFIT COST			555	383
Cost capitalized	(60)	(42)	(186)	(131)
Reconciliation to rate level	(1)	(11)	(36)	(70)
Cost charged to operating expenses	$ 124	$ 75	$ 333	$ 182

XML

Derivative Instruments And Hedging Activities - Changes In Fair Values Of Commodity Derivatives (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011
Con Edison [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	$ 6	[1]	$ (1)	[1]	$ 6	[1]	$ 3	[1]
Total deferred gains/(losses)	13	[1]	(53)	[1]	(85)	[1]	(59)	[1]
Net deferred gains/(losses)	19	[1]	(54)	[1]	(79)	[1]	(56)	[1]
Total pre-tax gain/(loss) recognized in income	10	[1]	40	[1]	(62)	[1]	120	[1]
Con Edison [Member] | Deferred Derivative Gains, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	5	[1]			5	[1]
Con Edison [Member] | Deferred Derivative Gains, Long-term [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	1	[1]	(2)	[1]	1	[1]
Total deferred gains/(losses)								[1]
Con Edison [Member] | Deferred Derivative Losses, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	51	[1]	12	[1]	89	[1]	80	[1]
Con Edison [Member] | Recoverable Energy Costs, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	(60)	[1]	(75)	[1]	(187)	[1]	(177)	[1]
Con Edison [Member] | Regulatory Assets, Long-Term [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	22	[1]	10	[1]	13	[1]	38	[1]
Con Edison [Member] | Regulatory Liabilities, Long-Term [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)			1	[1]			3	[1]
CECONY [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	6	[1]			6	[1]	3	[1]
Total deferred gains/(losses)	10	[1]	(40)	[1]	(67)	[1]	(47)	[1]
Net deferred gains/(losses)	16	[1]	(40)	[1]	(61)	[1]	(44)	[1]
CECONY [Member] | Deferred Derivative Gains, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	5	[1]			5	[1]
CECONY [Member] | Deferred Derivative Gains, Long-term [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	1	[1]	(1)	[1]	1	[1]
Total deferred gains/(losses)								[1]
CECONY [Member] | Deferred Derivative Losses, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	42	[1]	7	[1]	78	[1]	60	[1]
CECONY [Member] | Recoverable Energy Costs, Current [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	(52)	[1]	(53)	[1]	(164)	[1]	(134)	[1]
CECONY [Member] | Regulatory Assets, Long-Term [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)	20	[1]	6	[1]	19	[1]	27	[1]
CECONY [Member] | Regulatory Liabilities, Long-Term [Member]
Derivatives, Fair Value [Line Items]
Total deferred gains/(losses)			1	[1]			3	[1]
Non-Utility Revenue [Member]
Derivatives, Fair Value [Line Items]
Total pre-tax gain/(loss) recognized in income			(10)		(13)		(35)
Non-Utility Revenue [Member] | Con Edison [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income	1	[1],[2]	5	[1],[3]	(11)	[1],[4]	22	[1],[5]
Purchased Power Expense [Member]
Derivatives, Fair Value [Line Items]
Total pre-tax gain/(loss) recognized in income	30		(1)		75		59
Purchased Power Expense [Member] | Con Edison [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income	9	[1],[2]	29	[1],[3]	(49)	[1],[4]	81	[1],[5]
Gas Purchased For Resale [Member] | Con Edison [Member]
Derivatives, Fair Value [Line Items]
Pre-tax gain/(loss) recognized in income			$ 6	[1]	$ (2)	[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 September 30, 2012, Con Edison recorded in purchased power expense an unrealized pre-tax gain/(loss) of $30 million.

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

[4] For the nine months ended September 30, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $75 million, respectively.

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

XML

Other Material Contingencies - Total Guarantees (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 823	$ 760
Financial And Performance Guarantee For Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	764
Financial And Performance Guarantee For Intra-Company [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	16
Financial And Performance Guarantee Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	43
Guarantee Duration, 0 - 3 Years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	749
Guarantee Duration, 0 - 3 Years [Member] | Financial And Performance Guarantee For Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	696
Guarantee Duration, 0 - 3 Years [Member] | Financial And Performance Guarantee For Intra-Company [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	15
Guarantee Duration, 0 - 3 Years [Member] | Financial And Performance Guarantee Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	38
Guarantee Duration, 4 - 10 Years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	7
Guarantee Duration, 4 - 10 Years [Member] | Financial And Performance Guarantee For Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	2
Guarantee Duration, 4 - 10 Years [Member] | Financial And Performance Guarantee Other [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	5
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] | Financial And Performance Guarantee For Energy Transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	66
Guarantee Duration, Greater Than 10 Years [Member] | Financial And Performance Guarantee For Intra-Company [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 1

XML

Derivative Instruments And Hedging Activities - Number Of Derivative Contracts By Commodity Type (Detail)	9 Months Ended
	Sep. 30, 2012 Contract MWh MW
Description Of Derivative Activity Volume Electric Derivatives [Member] | Con Edison [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	576	[1]
MWhs	12,807,613	[2]
Number of Capacity Contracts	78	[1]
MW-Months	10,019	[2]
Description Of Derivative Activity Volume Electric Derivatives [Member] | CECONY [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	113	[1]
MWhs	3,271,000	[2]
Description Of Derivative Activity Volume Gas Derivatives [Member] | Con Edison [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	635	[1]
Dths	86,541,700	[2]
Number of Capacity Contracts	1,289	[1]
Description Of Derivative Activity Volume Gas Derivatives [Member] | CECONY [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	515	[1]
Dths	81,080,000	[2]
Number of Capacity Contracts	628	[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] Volumes are reported net of long and short positions.

XML

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Con Edison [Member]
Site Contingency [Line Items]
Regulatory assets	$ 8,974	$ 9,501
Con Edison [Member] | Asbestos Suits [Member]
Site Contingency [Line Items]
Accrued liability	10	10
Regulatory assets	10	10
Con Edison [Member] | Workers' Compensation [Member]
Site Contingency [Line Items]
Accrued liability	94	98
Regulatory assets	19	23
CECONY [Member]
Site Contingency [Line Items]
Regulatory assets	8,347	8,801
CECONY [Member] | Asbestos Suits [Member]
Site Contingency [Line Items]
Accrued liability	10	10
Regulatory assets	10	10
CECONY [Member] | Workers' Compensation [Member]
Site Contingency [Line Items]
Accrued liability	89	93
Regulatory assets	$ 19	$ 23

XML

Summary of Significant Accounting Policies - Earnings Per Common Share (Detail) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended						9 Months Ended
	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Sep. 30, 2012	Sep. 30, 2011
Earnings Per Share [Line Items]
Net income for common stock	$ 440	$ 214	$ 277	$ 383	$ 165	$ 311	$ 931	$ 860
Weighted average common shares outstanding - basic	292.9			292.9			292.9	292.5
Add: Incremental shares attributable to effect of potentially dilutive securities	1.7			1.7			1.7	1.7
Adjusted weighted average common shares outstanding - diluted	294.6			294.6			294.6	294.2
Net income for common stock per common share - basic	$ 1.50			$ 1.31			$ 3.18	$ 2.94
Net income for common stock per common share - diluted	$ 1.49			$ 1.30			$ 3.16	$ 2.92

XML

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended				9 Months Ended		12 Months Ended				9 Months Ended					9 Months Ended					9 Months Ended						9 Months Ended										9 Months Ended													9 Months Ended				9 Months Ended												12 Months Ended				9 Months Ended		12 Months Ended				9 Months Ended					9 Months Ended					9 Months Ended				9 Months Ended						9 Months Ended		12 Months Ended			9 Months Ended		12 Months Ended			9 Months Ended					9 Months Ended					9 Months Ended						9 Months Ended										9 Months Ended
	Dec. 31, 2011 Con Edison [Member]		Sep. 30, 2012 Con Edison [Member]		Sep. 30, 2012 Con Edison [Member] Derivatives Assets [Member]		Dec. 31, 2011 CECONY [Member]		Sep. 30, 2012 CECONY [Member]		Sep. 30, 2012 CECONY [Member] Derivatives Assets [Member]		Sep. 30, 2012 Commodity [Member] Con Edison [Member]	Dec. 31, 2011 Commodity [Member] Con Edison [Member]		Sep. 30, 2012 Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Commodity [Member] CECONY [Member]	Dec. 31, 2011 Commodity [Member] CECONY [Member]		Sep. 30, 2012 Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Other Assets [Member] Con Edison [Member]		Dec. 31, 2011 Other Assets [Member] Con Edison [Member]		Sep. 30, 2012 Other Assets [Member] Con Edison [Member] Derivatives Assets [Member]		Sep. 30, 2012 Other Assets [Member] CECONY [Member]		Dec. 31, 2011 Other Assets [Member] CECONY [Member]		Sep. 30, 2012 Other Assets [Member] CECONY [Member] Derivatives Assets [Member]	Sep. 30, 2012 Interest Rate Contract [Member] Con Edison [Member]	Dec. 31, 2011 Interest Rate Contract [Member] Con Edison [Member]		Sep. 30, 2012 Interest Rate Contract [Member] Con Edison [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Level 1 [Member] Con Edison [Member]		Dec. 31, 2011 Level 1 [Member] Con Edison [Member]		Sep. 30, 2012 Level 1 [Member] CECONY [Member]		Dec. 31, 2011 Level 1 [Member] CECONY [Member]		Sep. 30, 2012 Level 1 [Member] Commodity [Member] Con Edison [Member]	Dec. 31, 2011 Level 1 [Member] Commodity [Member] Con Edison [Member]		Sep. 30, 2012 Level 1 [Member] Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Level 1 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2011 Level 1 [Member] Commodity [Member] CECONY [Member]	Sep. 30, 2012 Level 1 [Member] Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Level 1 [Member] Other Assets [Member] Con Edison [Member]		Dec. 31, 2011 Level 1 [Member] Other Assets [Member] Con Edison [Member]		Sep. 30, 2012 Level 1 [Member] Other Assets [Member] Con Edison [Member] Derivatives Assets [Member]	Sep. 30, 2012 Level 1 [Member] Other Assets [Member] CECONY [Member]		Dec. 31, 2011 Level 1 [Member] Other Assets [Member] CECONY [Member]		Sep. 30, 2012 Level 1 [Member] Other Assets [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2011 Level 2 [Member] Con Edison [Member]		Sep. 30, 2012 Level 2 [Member] Con Edison [Member]		Sep. 30, 2012 Level 2 [Member] Con Edison [Member] Derivatives Assets [Member]		Dec. 31, 2011 Level 2 [Member] CECONY [Member]		Sep. 30, 2012 Level 2 [Member] CECONY [Member]		Sep. 30, 2012 Level 2 [Member] CECONY [Member] Derivatives Assets [Member]		Sep. 30, 2012 Level 2 [Member] Commodity [Member] Con Edison [Member]	Dec. 31, 2011 Level 2 [Member] Commodity [Member] Con Edison [Member]		Sep. 30, 2012 Level 2 [Member] Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Level 2 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2011 Level 2 [Member] Commodity [Member] CECONY [Member]		Sep. 30, 2012 Level 2 [Member] Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Level 2 [Member] Other Assets [Member] Con Edison [Member]		Sep. 30, 2012 Level 2 [Member] Other Assets [Member] Con Edison [Member] Derivatives Assets [Member]		Sep. 30, 2012 Level 2 [Member] Other Assets [Member] CECONY [Member]		Sep. 30, 2012 Level 2 [Member] Other Assets [Member] CECONY [Member] Derivatives Assets [Member]	Sep. 30, 2012 Level 2 [Member] Interest Rate Contract [Member] Con Edison [Member]	Sep. 30, 2012 Level 2 [Member] Interest Rate Contract [Member] Con Edison [Member] Derivatives Liabilities [Member]		Dec. 31, 2011 Level 3 [Member] Con Edison [Member]		Sep. 30, 2012 Level 3 [Member] Con Edison [Member]	Sep. 30, 2012 Level 3 [Member] Con Edison [Member] Derivatives Assets [Member]		Dec. 31, 2011 Level 3 [Member] CECONY [Member]		Sep. 30, 2012 Level 3 [Member] CECONY [Member]	Sep. 30, 2012 Level 3 [Member] CECONY [Member] Derivatives Assets [Member]		Sep. 30, 2012 Level 3 [Member] Commodity [Member] Con Edison [Member]	Dec. 31, 2011 Level 3 [Member] Commodity [Member] Con Edison [Member]		Sep. 30, 2012 Level 3 [Member] Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Level 3 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2011 Level 3 [Member] Commodity [Member] CECONY [Member]		Sep. 30, 2012 Level 3 [Member] Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Level 3 [Member] Other Assets [Member] Con Edison [Member]		Dec. 31, 2011 Level 3 [Member] Other Assets [Member] Con Edison [Member]		Sep. 30, 2012 Level 3 [Member] Other Assets [Member] Con Edison [Member] Derivatives Assets [Member]		Sep. 30, 2012 Level 3 [Member] Other Assets [Member] CECONY [Member]		Dec. 31, 2011 Level 3 [Member] Other Assets [Member] CECONY [Member]		Sep. 30, 2012 Level 3 [Member] Other Assets [Member] CECONY [Member] Derivatives Assets [Member]	Sep. 30, 2012 Level 3 [Member] Interest Rate Contract [Member] Con Edison [Member]	Dec. 31, 2011 Level 3 [Member] Interest Rate Contract [Member] Con Edison [Member]		Sep. 30, 2012 Level 3 [Member] Interest Rate Contract [Member] Con Edison [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Netting Adjustments [Member] Con Edison [Member]		Dec. 31, 2011 Netting Adjustments [Member] Con Edison [Member]		Sep. 30, 2012 Netting Adjustments [Member] CECONY [Member]		Dec. 31, 2011 Netting Adjustments [Member] CECONY [Member]		Sep. 30, 2012 Netting Adjustments [Member] Commodity [Member] Con Edison [Member]		Dec. 31, 2011 Netting Adjustments [Member] Commodity [Member] Con Edison [Member]		Sep. 30, 2012 Netting Adjustments [Member] Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Netting Adjustments [Member] Commodity [Member] CECONY [Member]		Dec. 31, 2011 Netting Adjustments [Member] Commodity [Member] CECONY [Member]		Sep. 30, 2012 Netting Adjustments [Member] Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]		Sep. 30, 2012 Netting Adjustments [Member] Other Assets [Member] Con Edison [Member]		Sep. 30, 2012 Netting Adjustments [Member] Other Assets [Member] Con Edison [Member] Derivatives Assets [Member]		Sep. 30, 2012 Netting Adjustments [Member] Other Assets [Member] CECONY [Member]		Sep. 30, 2012 Netting Adjustments [Member] Other Assets [Member] CECONY [Member] Derivatives Assets [Member]
Fair Value Measurements Of Financial Instruments [Line Items]
Transfer in	$ 32	[1],[2],[3]			$ 105	[1],[3]	$ 31	[1],[2],[3]			$ 95	[1],[3]				$ 60	[1],[3]				$ 22	[1],[3]					$ 24	[1],[3]									$ 8	[1],[3]												$ 7	[1],[3]			$ 7	[1],[3]											$ 26	[1],[2],[3]			$ 105	[1],[3]	$ 25	[1],[2],[3]			$ 95	[1],[3]				$ 50	[1],[3]				$ 12	[1],[3]			$ 24	[1],[3]					$ 8	[1],[3]	$ 6	[1],[2],[3]				$ 6	[1],[2],[3]							$ 3	[1],[3]				$ 3	[1],[3]
Transfer out	(32)	[1],[2],[3]			(105)	[1],[3]	(31)	[1],[2],[3]			(95)	[1],[3]				(60)	[1],[3]				(22)	[1],[3]					(24)	[1],[3]									(8)	[1],[3]												(2)	[1],[3]															(6)	[1],[2],[3]					(6)	[1],[2],[3]								(10)	[1],[3]				(10)	[1],[3]											(26)	[1],[2],[3]		(105)	[1],[3]	(25)	[1],[2],[3]		(95)	[1],[3]				(48)	[1],[3]				(12)	[1],[3]					(24)	[1],[3]									(8)	[1],[3]
Commodity Total	245		259				190		219																		51						27						105		79		98		76															2					2	64		177				8		112																72				16				186		23			101		12																	23						12						(46)	[4]	(84)	[4]	(3)	[4]	5	[4]															(46)	[4]			(3)	[4]
Derivative assets			208	[5]					192	[5]				70	[6]				24	[6]			51	[6]	175	[5]	208		27	[6]	166	[5]	192						103	[5]			96	[5]				3	[6]							2	[6]	76	[5]	103	2	[6]	76	[5]	96			105	[5]					96	[5]				64	[6]				8	[6]			48	[6]			16	[6]	1															87	[6]				11	[6]			47	[6]	99	[5]	105		12	[6]	90	[5]	95																(84)	[4],[6]					5	[4],[6]			(46)	[4],[6]			(3)	[4],[6]
Total liabilities	217		90				122		42																														9		12		8		4																					242		160				141		70																								157		26			18																															(105)	[4]	(194)	[4]	(36)	[4]	(41)	[4]
Derivative liabilities	$ 209	[6]					$ 122	[6]					$ 84	$ 209		$ 84	[6]	$ 42	$ 122		$ 42	[6]												$ 6	$ 8	[7]	$ 6	[7]			$ 12	[6]			$ 4	[6]	$ 4	$ 12		$ 9	[6]	$ 1	$ 4	$ 8	[6]											$ 242	[6]					$ 141	[6]					$ 114	$ 222		$ 154	[6]	$ 68	$ 122		$ 70	[6]								$ (2)	$ 6	[7]	$ 149	[6]				$ 18	[6]				$ 71	$ 169		$ 26	[6]	$ 9	$ 37															$ 8	$ 8	[7]					$ (194)	[4],[6]			$ (41)	[4],[6]	$ (105)	[4]	$ (194)	[4]	$ (105)	[4],[6]	$ (36)	[4]	$ (41)	[4]	$ (36)	[4],[6]

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

[2] 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.

[3] Transferred between Level 3 and Levels 1 and 2 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall. Other assets and interest rate contract were transferred as of March 31, 2012.

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

[6] 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.

[7] See Note J.

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Capitalization (Tables)

9 Months Ended

Sep. 30, 2012

Carrying Amounts and Fair Values of Long-term Debt

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

(Millions of Dollars)	September 30, 2012				December 31, 2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison		$10,769		$13,197		$10,673		$12,744
CECONY		$  9,845		$12,001		$  9,745		$11,593

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Financial Information By Business Segment - Additional Information (Detail) (Con Edison Development [Member], USD $) In Millions, unless otherwise specified	1 Months Ended
	Jul. 31, 2012 MW	Oct. 31, 2012 Subsequent Event [Member] Company	Jul. 31, 2012 Alpaugh [Member]	Jul. 31, 2012 Alpaugh [Member] Contingent consideration [Member]	Jul. 31, 2012 Alpaugh [Member] Construction work in progress [Member]	Jul. 31, 2012 Alpaugh [Member] Deposits relating to power purchase agreements [Member]	Jul. 31, 2012 Alpaugh [Member] Construction [Member]	Oct. 31, 2012 California [Member] Subsequent Event [Member] MW	Oct. 31, 2012 California [Member] Subsequent Event [Member] Construction work in progress [Member]	Oct. 31, 2012 California [Member] Subsequent Event [Member] Deposits relating to power purchase agreements [Member]	Oct. 31, 2012 California [Member] Subsequent Event [Member] Construction [Member]
Segment Reporting Information [Line Items]
Solar energy purchased	70							40
Purchase price of solar energy development company			$ 288	$ 2	$ 284	$ 4	$ 350	$ 51	$ 39	$ 12	$ 200
Number of companies purchased		2

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Other Postretirement Benefits - Additional Information (Detail) (Other Postretirement Benefit Plans, Defined Benefit [Member], USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012
Con Edison [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Expected contributions	$ 83
Contributions to benefit plans	34
CECONY [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Expected contributions	71
Contributions to benefit plans	$ 28

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Capitalization - Carrying Amounts And Fair Values Of Long-term Debt (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Consolidated Edison Inc [Member]
Carrying Amount	$ 10,769	$ 10,673
Fair Value	13,197	12,744
CECONY [Member]
Carrying Amount	9,845	9,745
Fair Value	$ 12,001	$ 11,593

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Derivative Instruments And Hedging Activities - Narrative (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011
Investment Holdings [Line Items]
Increase in the fair value of interest swap	$ 1				$ 2
Con Edison [Member]
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	118				118
Makeup of net credit exposure, with investment-grade counterparties	44				44
Makeup of net credit exposure with commodity exchange brokers	25				25
Makeup of net credit exposure independent system operators	47
Makeup of net credit exposure non-rated counterparties	2
Number of contracts, considered derivatives					1289
Unrealized gain (loss) on derivatives	10	[1]	40	[1]	(62)	[1]	120	[1]
CECONY [Member]
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	13				13
Makeup of net credit exposure, with investment-grade counterparties	3				3
Makeup of net credit exposure with commodity exchange brokers	10				10
Number of contracts, considered derivatives					628
Interest Rate Swap [Member]
Investment Holdings [Line Items]
Unrealized gain (loss) on derivatives					$ 6
Derivative, fixed interest rate	6.09%				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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Hurricane Sandy - Additional Information (Detail) (Subsequent Event [Member])	1 Months Ended
	Oct. 31, 2012 Customer
CECONY [Member]
Number of customer	950,000
Orange And Rockland Utilities Inc [Member]
Number of customer	250,000

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Other Material Contingencies - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	9 Months Ended					9 Months Ended
	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2012 Leases [Member]	Sep. 30, 2012 Energy [Member]	Sep. 30, 2012 Construction [Member]	Sep. 30, 2012 Tax Deficiency Paid In December 2005 [Member]	Sep. 30, 2012 Interest In April 2006 [Member]	Sep. 30, 2012 Disallowance Of Tax 1998-2007 [Member]	Dec. 31, 2011 Disallowance Of Tax 2011 [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	(73)	(55)
Gross investment in leverage leases	228	234
Deferred tax liabilities	301	289
Tax deficiency paid to IRS						0.3
Interest paid related to tax deficiency							0.2
Disallowed deduction								416	35	40	41	42
Tax savings from lease in lease out transactions	248
Interest required to be paid	122
Guarantee obligations maximum exposure	823	760
Guarantees issued			7	25	11
Maximum potential obligation	$ 5

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General

9 Months Ended

Sep. 30, 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 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2012 and June 30, 2012. 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 and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2012 and June 30, 2012. 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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Environmental Matters - Accrued Liabilities and Regulatory Assets (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Con Edison [Member]
Accrued Liabilities:
Regulatory assets	$ 8,974	$ 9,501
Con Edison [Member] | Manufactured Gas Plant Sites [Member]
Accrued Liabilities:
Accrued liabilities	466	422
Con Edison [Member] | Other Superfund Sites [Member]
Accrued Liabilities:
Accrued liabilities	71	67
Con Edison [Member] | Superfund Sites [Member]
Accrued Liabilities:
Accrued liabilities	537	489
Regulatory assets	722	681
CECONY [Member]
Accrued Liabilities:
Regulatory assets	8,347	8,801
CECONY [Member] | Manufactured Gas Plant Sites [Member]
Accrued Liabilities:
Accrued liabilities	352	307
CECONY [Member] | Other Superfund Sites [Member]
Accrued Liabilities:
Accrued liabilities	71	66
CECONY [Member] | Superfund Sites [Member]
Accrued Liabilities:
Accrued liabilities	423	373
Regulatory assets	$ 607	$ 564

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Other Material Contingencies (Tables)

9 Months Ended

Sep. 30, 2012

Total Guarantees

A summary, by type and term, of Con Edison’s total guarantees at September 30, 2012 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions		$696		$2		$66		$764
Intra-company guarantees		15		—		1		16
Other guarantees		38		5		—		43
TOTAL		$749		$7		$67		$823

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Environmental Matters (Tables)

9 Months Ended

Sep. 30, 2012

Accrued Liabilities and Regulatory Assets

The accrued liabilities and regulatory assets related to Superfund Sites at September 30, 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		$352		$307
Other Superfund Sites		71		67		71		66
Total		$537		$489		$423		$373
Regulatory assets		$722		$681		$607		$564

Environmental Remediation Costs

Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites for the three and nine months ended September 30, 2012 and 2011, were as follows:

	For the Three Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred		$3		$9		$1		$9
Insurance recoveries received		—		—		—		—

	For the Nine Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred		$18		$24		$15		$22
Insurance recoveries received		—		—		—		—

Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at September 30, 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		$94		$98		$89		$93
Regulatory assets – workers’ compensation		$19		$23		$19		$23

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Derivative Instruments And Hedging Activities - Aggregate Fair Value Of All Derivative Instruments With Credit-Risk-Related Contingent Features (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012
Con Edison [Member]
Derivatives, Fair Value [Line Items]
Aggregate fair value - net liabilities	$ 62	[1]
Collateral posted	14	[1]
Con Edison [Member] | Additional Collateral Aggregate Fair Value Down Below Investment Grade [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	27
Additional collateral (b) (downgrade one level from current ratings (c))	85	[1],[2],[3],[4]
CECONY [Member]
Derivatives, Fair Value [Line Items]
Aggregate fair value - net liabilities	41	[1]
Collateral posted	9	[1]
CECONY [Member] | Additional Collateral Required Due To Loss Of Unsecured Credit [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	25
CECONY [Member] | Additional Collateral Aggregate Fair Value Down Below Investment Grade [Member]
Derivatives, Fair Value [Line Items]
Additional collateral (b) (downgrade one level from current ratings (c))	$ 45	[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 September 30, 2012, would have amounted to an estimated $25 million for Con Edison. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

[2] 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 September 30, 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 $27 million.

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Environmental Matters - Environmental Remediation Costs (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Con Edison [Member]
Site Contingency [Line Items]
Remediation costs incurred	$ 3	$ 9	$ 18	$ 24
Insurance recoveries received
CECONY [Member]
Site Contingency [Line Items]
Remediation costs incurred	1	9	15	22
Insurance recoveries received

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Financial Information by Business Segment (Tables)

9 Months Ended

Sep. 30, 2012

Financial Data for the Business Segments

The financial data for the business segments are as follows:

	For the Three Months Ended September 30,
	Operating revenues					Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012		2011			2012			2011			2012		2011		2012			2011
CECONY
Electric		$2,611		$2,644			$    4			$    3			$179		$166		$812			$758
Gas		189		197			1			1			31		28		(21	)		(23	)
Steam		68		76			20			20			15		15		(37	)		(33	)
Consolidation adjustments		—		—			(25	)		(24	)		—		—		—			—
Total CECONY		$2,868		$2,917			$  —			$  —			$225		$209		$754			$702
O&R
Electric		$   199		$   217			$  —			$  —			$  10		$    9		$  50			$  44
Gas		27		24			—			—			3		3		(6	)		(6	)
Total O&R		$   226		$   241			$  —			$  —			$  13		$  12		$  44			$  38
Competitive energy businesses		$   344		$   472			$    2			$    3			$    2		$    1		$  53			$  16
Other*		—		(1	)		(2	)		(3	)		—		—		—			—
Total Con Edison		$3,438		$3,629			$  —			$  —			$240		$222		$851			$756

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

	For the Nine Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012			2011			2012			2011			2012		2011		2012			2011
CECONY
Electric		$6,307			$6,378			$  11			$    9			$527		$489		$1,383			$1,326
Gas		1,017			1,156			4			4			89		82		255			212
Steam		414			508			58			59			48		47		40			81
Consolidation adjustments		—			—			(73	)		(72	)		—		—		—			—
Total CECONY		$7,738			$8,042			$  —			$  —			$664		$618		$1,678			$1,619
O&R
Electric		$   457			$   507			$  —			$  —			$  28		$  26		$     74			$     69
Gas		144			153			—			—			11		10		26			22
Total O&R		$   601			$   660			$  —			$  —			$  39		$  36		$   100			$     91
Competitive energy businesses		$   954			$1,286			$    6			$    9			$    6		$    5		$   111			$     75
Other*		(6	)		(16	)		(6	)		(9	)		—		—		(3	)		(4	)
Total Con Edison		$9,287			$9,972			$  —			$  —			$709		$659		$1,886			$1,781

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

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Derivative Instruments and Hedging Activities (Tables)

9 Months Ended

Sep. 30, 2012

Energy Price Hedging Fair Values

The fair values of the Companies’ commodity derivatives at September 30, 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		$(92	)		$(249	)		$(48	)		$(144	)
Impact of netting of cash collateral		59			110			33			46
Fair value of net derivative assets/(liabilities) – net		$(33	)		$(139	)		$(15	)		$  (98	)

Fair Values Of Companies' Commodity Derivatives

The fair values of the Companies’ commodity derivatives at September 30, 2012 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets		$   91			$ 30
Long-term	Other deferred charges and non-current assets		19			10
Total derivative assets			$ 110			$ 40
Impact of netting			(59	)		(13	)
Net derivative assets			$   51			$ 27

Derivative Liabilities
Current	Fair value of derivative liabilities	$ 149		$ 60
Long-term	Fair value of derivative liabilities	53		28
Total derivative liabilities		$ 202		$ 88
Impact of netting		(118	)	(46	)
Net derivative liabilities		$   84		$ 42

(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
Derivative Assets
Current	Other current assets		$ 139			$  16
Long-term	Other deferred charges and non-current assets		26			14
Total derivative assets			$ 165			$  30
Impact of netting			(95	)		(6	)
Net derivative assets			$   70			$  24
Derivative Liabilities
Current	Fair value of derivative liabilities		$ 331			$127
Long-term	Fair value of derivative liabilities		83			48
Total derivative liabilities			$ 414			$175
Impact of netting			(205	)		(53	)
Net derivative liabilities			$ 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 Fair Values Of Commodity Derivatives

The following tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2012:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended September 30, 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		$   5			$   5
Long-term	Deferred derivative gains		1			1
Total deferred gains/(losses)			$   6			$   6
Current	Deferred derivative losses		$ 51			$ 42
Current	Recoverable energy costs		(60	)		(52	)
Long-term	Deferred derivative losses		22			20
Total deferred gains/(losses)			$ 13			$ 10
Net deferred gains/(losses)			$ 19			$ 16
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$   9	(b)		$  —
	Gas purchased for resale		—			—
	Non-utility revenue		1	(b)		—
Total pre-tax gain/(loss) recognized in income			$ 10			$  —

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

(b) For the three months ended September 30, 2012, Con Edison recorded in purchased power expense an unrealized pre-tax gain/(loss) of $30 million.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 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		$     5			$     5
Long-term	Deferred derivative gains		1			1
Total deferred gains/(losses)			$     6			$     6
Current	Deferred derivative losses		$   89			$   78
Current	Recoverable energy costs		(187	)		(164	)
Long-term	Deferred derivative losses		13			19
Total deferred gains/(losses)			$  (85	)		$  (67	)
Net deferred gains/(losses)			$  (79	)		$  (61	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$  (49	)(b)		$    —
	Gas purchased for resale		(2	)		—
	Non-utility revenue		(11	)(b)		—
Total pre-tax gain/(loss) recognized in income			$  (62	)		$    —

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

(b) For the nine months ended September 30, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $75 million, respectively.

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

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

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

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

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains		$    —			$    —
Long-term	Regulatory liabilities		3			3
Total deferred gains/(losses)			$     3			$     3
Current	Deferred derivative losses		$   80			$   60
Current	Recoverable energy costs		(177	)		(134	)
Long-term	Regulatory assets		38			27
Total deferred gains/(losses)			$  (59	)		$  (47	)
Net deferred gains/(losses)			$  (56	)		$  (44	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$   81	(b)		$    —
	Gas purchased for resale		17			—
	Non-utility revenue		22	(b)		—
Total pre-tax gain/(loss) recognized in income			$ 120			$    —

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

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

Number Of Derivative Contracts By Commodity Type

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)		MW-Months (b)		Number of Contracts (a)		dths (b)		Total Number of Contracts (a)
Con Edison		576		12,807,613		78		10,019		635		86,541,700		1,289
CECONY		113		3,271,000		—		—		515		81,080,000		628

(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

The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position and collateral posted at September 30, 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		$62			$41
Collateral posted		$14			$  9
Additional collateral (b) (downgrade one level from current ratings (c))		$ —			$ —
Additional collateral (b) (downgrade to below investment grade from current ratings (c))		$85	(d)		$45	(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 September 30, 2012, would have amounted to an estimated $25 million for Con Edison. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

(b) 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 September 30, 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 $27 million.

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CONSOLIDATED STATEMENT OF COMMON SHAREHOLDERS EQUITY (USD $) In Millions, except Share data	Total	CECONY [Member]	Common Stock [Member]	Common Stock [Member] CECONY [Member]	Additional Paid-In Capital [Member]	Additional Paid-In Capital [Member] CECONY [Member]	Retained Earnings [Member]	Retained Earnings [Member] CECONY [Member]	Treasury Stock [Member]	Capital Stock Expense [Member]	Capital Stock Expense [Member] CECONY [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Accumulated Other Comprehensive Income/(Loss) [Member] CECONY [Member]	Repurchased Con Edison Stock [Member] CECONY [Member]
BALANCE at Dec. 31, 2010	$ 11,061	$ 9,923	$ 31	$ 589	$ 4,915	$ 4,234	$ 7,220	$ 6,132	$ (1,001)	$ (64)	$ (64)	$ (40)	$ (6)	$ (962)
BALANCE (In Shares) at Dec. 31, 2010			291,616,334	235,488,094					23,210,700
Net income for common stock	311						311
Net Income		271						271
Common stock dividends	(175)	(170)					(175)	(170)
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			656,049
Cumulative preferred dividends		(3)						(3)
Issuance of common shares - dividend reinvestment and employee stock plans	31		1		30
Other comprehensive income	3											3
BALANCE at Mar. 31, 2011	11,231	10,021	32	589	4,945	4,234	7,356	6,230		(64)	(64)	(37)	(6)	(962)
BALANCE (In Shares) at Mar. 31, 2011			292,272,383	235,488,094
BALANCE at Dec. 31, 2010	11,061	9,923		589		4,234			(1,001)	(64)	(64)		(6)	(962)
BALANCE (In Shares) at Dec. 31, 2010				235,488,094					23,210,700
Net income for common stock	860	779
Net Income	869	788
Cumulative preferred dividends	(9)
BALANCE at Sep. 30, 2011	11,454	10,192		589		4,234				(64)	(64)		(6)	(962)
BALANCE (In Shares) at Sep. 30, 2011				235,488,094
BALANCE at Mar. 31, 2011	11,231	10,021	32	589	4,945	4,234	7,356	6,230	(1,001)	(64)	(64)	(37)	(6)	(962)
BALANCE (In Shares) at Mar. 31, 2011			292,272,383	235,488,094					23,210,700
Net income for common stock	165						165
Net Income		160						160
Common stock dividends	(175)	(170)					(175)	(170)
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			603,513						(182,942)
Cumulative preferred dividends		(3)						(3)
Issuance of common shares - dividend reinvestment and employee stock plans	37				32				5
Common stock repurchases	(9)								(9)
Common stock repurchases (In Shares)									178,942
Other comprehensive income	2											2
BALANCE at Jun. 30, 2011	11,251	10,008	32	589	4,977	4,234	7,346	6,217	(1,005)	(64)	(64)	(35)	(6)	(962)
BALANCE (In Shares) at Jun. 30, 2011			292,875,896	235,488,094					23,206,700
Net income for common stock	383	353					383
Net Income	386	356						356
Common stock dividends	(176)	(169)					(176)	(169)
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			8,000						(554,356)
Cumulative preferred dividends	(3)	(3)						(3)
Issuance of common shares - dividend reinvestment and employee stock plans	25				6				19
Common stock repurchases	(31)								(31)
Common stock repurchases (In Shares)									546,356
Other comprehensive income	2											2
BALANCE at Sep. 30, 2011	11,454	10,192	32	589	4,983	4,234	7,553	6,401	(1,017)	(64)	(64)	(33)	(6)	(962)
BALANCE (In Shares) at Sep. 30, 2011			292,883,896	235,488,094					23,198,700
BALANCE at Dec. 31, 2011	11,436	10,218	32	589	4,991	4,234	7,568	6,429	(1,033)	(64)	(64)	(58)	(8)	(962)
BALANCE (In Shares) at Dec. 31, 2011			292,888,521	235,488,094					23,194,075
Net income for common stock	277						277
Net Income		276						276
Common stock dividends	(177)	(171)					(177)	(171)
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			(7,225)						7,225
Cumulative preferred dividends		(3)						(3)
Issuance of common shares - dividend reinvestment and employee stock plans	(2)								(2)
Preferred stock redemption	4	4								4	4
Other comprehensive income	7											7
BALANCE at Mar. 31, 2012	11,545	10,324	32	589	4,991	4,234	7,668	6,531	(1,035)	(60)	(60)	(51)		(962)
BALANCE (In Shares) at Mar. 31, 2012			292,881,296	235,488,094					23,201,300
BALANCE at Dec. 31, 2011	11,436	10,218		589	4,991	4,234							(8)	(962)
BALANCE (In Shares) at Dec. 31, 2011				235,488,094
Net income for common stock	931	824
Net Income	934	827
Cumulative preferred dividends	(3)
BALANCE at Sep. 30, 2012	11,842	10,532		589	4,991	4,234				(61)	(60)		(10)	(962)
BALANCE (In Shares) at Sep. 30, 2012				235,488,094
BALANCE at Mar. 31, 2012	11,545	10,324	32	589	4,991	4,234	7,668	6,531	(1,035)	(60)		(51)	(8)	(962)
BALANCE (In Shares) at Mar. 31, 2012			292,881,296	235,488,094					23,201,300
Net income for common stock	214						214
Net Income		163						163
Common stock dividends	(178)	(171)					(178)	(171)
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			1,700						(1,700)
Issuance of common shares - dividend reinvestment and employee stock plans	(1)									(1)
Other comprehensive income	(1)	(2)										(1)	(2)
BALANCE at Jun. 30, 2012	11,579	10,314	32	589	4,991	4,234	7,704	6,523	(1,035)	(61)	(60)	(52)	(10)	(962)
BALANCE (In Shares) at Jun. 30, 2012			292,882,996	235,488,094					23,199,600
Net income for common stock	440	389					440
Net Income	440	389						389
Common stock dividends	(177)	(171)					(177)	(171)
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			(11,100)						11,100
Issuance of common shares - dividend reinvestment and employee stock plans	(2)								(2)
Other comprehensive income	2											2
BALANCE at Sep. 30, 2012	$ 11,842	$ 10,532	$ 32	$ 589	$ 4,991	$ 4,234	$ 7,967	$ 6,741	$ (1,037)	$ (61)	$ (60)	$ (50)	$ (10)	$ (962)
BALANCE (In Shares) at Sep. 30, 2012			292,871,896	235,488,094					23,210,700

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2012

Assets and Liabilities Measured at Fair Value on Recurring Basis

Assets and liabilities measured at fair value on a recurring basis as of September 30, 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			$  2		$  48			$  16			$   47			$ 12			$  (46	)		$  (3	)		$   51			$  27
Transfer in (5) (6)		—			—		24			—			—			—			—			—			24			—
Transfer out (5) (6)		—			—		—			—			(24	)		—			—			—			(24	)		—
Commodity Total		$    2			$  2		$  72			$  16			$   23			$ 12			$  (46	)		$  (3	)		$ 51			$  27
Other assets		103			96		—			1			105			95			—			—			208			192
Transfer in (5) (6)		—			—		105			95			—			—			—			—			105			95
Transfer out (5) (6)		—			—		—			—			(105	)		(95	)		—			—			(105	)		(95	)
Other assets (3)		$103			$96		$105			$  96			$    —			$  —			$    —			$  —			$ 208			$192
Total		$105			$98		$177			$112			$   23			$ 12			$  (46	)		$  (3	)		$ 259			$219
Derivative liabilities:
Commodity		$    4			$  1		$114			$  68			$   71			$   9			$(105	)		$(36	)		$   84			$  42
Transfer in (5) (6)		7			7		50			12			3			3			—			—			60			22
Transfer out (5) (6)		(2	)		—		(10	)		(10	)		(48	)		(12	)		—			—			(60	)		(22	)
Commodity Total (1)		$9			$  8		$154			$  70			$   26			$  —			$(105	)		$(36	)		$   84			$  42
Interest rate contract		—			—		(2	)		—			8			—			—			—			6			—
Transfer in (5) (6)		—			—		8			—			—			—			—			—			8			—
Transfer out (5) (6)		—			—		—			—			(8	)		—			—			—			(8	)		—
Interest rate contract (2)		$   —			$ —		$    6			$ —			$    —			$  —			$    —			$  —			$     6			$   —
Total		$    9			$  8		$160			$70			$   26			$  —			$(105	)		$(36	)		$   90			$  42

(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 between Level 3 and Levels 1 and 2 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall. Other assets and interest rate contract were transferred as of March 31, 2012.

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

The managers of the risk management groups report to the Companies’ Vice President and Treasurer.

	Fair Value of Level 3 at September 30, 2012 (Millions of Dollars)			Valuation Techniques	Unobservable Inputs	Range
Con Edison—Commodity
Electricity Swaps	$	(9	)	Discounted Cash Flow	Forward prices (1)	$22-$64 per MWH
Electricity Wholesale Contract		4		Discounted Cash Flow	Auction prices (2) New Jersey solar renewable energy credit (SREC) (2)	$29-$52 per MWH $85 per SREC
Standard Offer Capacity Agreements		(12	)	Discounted Cash Flow	Forward capacity prices (1) Forward price escalator (1) Present value factor (1)	$166 MW per day 0%-3% 1.66%
Transmission Congestion Contracts / Financial Transmission Rights		14		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (2) Discount to adjust auction prices for historical monthly realized settlements (2) Historical line loss factor (1)	17.5%-38% (3)%-26.5% 8%
Total Con Edison—Commodity	$	(3	)
CECONY—Commodity
Transmission Congestion Contracts	$	12		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (2) Discount to adjust auction prices for historical monthly realized settlements (2)	17.5%-38% (3)%- 26.5%

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

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

Reconciliation of the Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2012 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30, 2012
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 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 September 30, 2012
Con Edison
Derivatives:
Commodity		$(61	)		$(15	)		$19		$7		$—		$—		$25		$22		$  (3	)
CECONY
Derivatives:
Commodity		$(10	)		$  (9	)		$  8		$7		$—		$—		$  5		$11		$ 12

	For the Nine Months Ended September 30, 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 September 30, 2012
Con Edison
Derivatives:
Commodity		$(62)		$(97)		$11		$18		$—		$—		$106		$     21			$ (3)
Interest rate contract		(8)		(1)		—		—		—		—		1		8(2	)		—
Other assets (1)		99		3		3		—		—		—		—		(105	)(2)		—
Total		$  29		$(95)		$14		$18		$—		$—		$107		$   (76)			$ (3)
CECONY
Derivatives:
Commodity		$  (7)		$(25)		$  8		$15		$—		$—		$  12		$    9(2	)		$ 12
Other assets (1)		90		3		2		—		—		—		—		(95	)(2)		—
Total		$  83		$(22)		$10		$15		$—		$—		$  12		$   (86)			$ 12

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

(2) Other assets and interest rate contract were transferred as of March 31, 2012.

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

	For the Three Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity		$ (25	)		$(37	)		$ 9			$8		$—		$—		$14		$24		$    (7	)
Interest rate contract		(10	)		(1	)		1			—		—		—		1		—		(9	)
Other assets (1)		106			(3	)		(3	)		—		—		—		—		—		100
Total		$  71			$(41	)		$ 7			$8		$—		$—		$15		$24		$   84
CECONY
Derivatives:
Commodity		$   —			$  (8	)		$ 1			$8		$—		$—		$  3		$  9		$   13
Other assets (1)		96			(3	)		(2	)		—		—		—		—		—		91
Total		$  96			$(11	)		$(1	)		$8		$—		$—		$  3		$  9		$ 104

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

	For the Nine Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity		$ (88	)		$(59	)		$54			$22		$—		$—		$35			$29		$    (7	)
Interest rate contract		(10	)		(3	)		1			—		—		—		3			—		(9	)
Other assets (1)		101			—			(1	)		—		—		—		—			—		100
Total		$    3			$(62	)		$54			$22		$—		$—		$38			$29		$   84
CECONY
Derivatives:
Commodity		$ (26	)		$(11	)		$22			$18		$—		$—		$ (4	)		$14		$   13
Other assets (1)		92			—			(1	)		—		—		—		—			—		91
Total		$  66			$(11	)		$21			$18		$—		$—		$ (4	)		$14		$ 104

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

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Pension Benefits - Additional Information (Detail) (Pension Benefits [Member], USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012
Pension And Other Employee Benefit Plans [Line Items]
Estimated future employer contributions	$ 775
CECONY [Member]
Pension And Other Employee Benefit Plans [Line Items]
Estimated future employer contributions	721
Funds made to non-qualified supplemental plan	$ 12

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Derivative Instruments And Hedging Activities - Fair Values Of Companies' Commodity Derivatives (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Con Edison [Member] | Derivatives Assets [Member]
Derivatives And Hedging Activities [Line Items]
Current Other current assets	$ 110	$ 165
Impact of netting	(59)	(95)
Net derivative assets	51	70
Con Edison [Member] | Derivatives Assets [Member] | Other Current Assets [Member]
Derivatives And Hedging Activities [Line Items]
Current Other current assets	91	139
Con Edison [Member] | Derivatives Assets [Member] | Other Deferred Charges And Non-Current Assets [Member]
Derivatives And Hedging Activities [Line Items]
Current Other current assets	19	26
Con Edison [Member] | Derivatives Liabilities [Member]
Derivatives And Hedging Activities [Line Items]
Current Fair value of derivative liabilities	202	414
Impact of netting	(118)	(205)
Net derivative liabilities	84	209
Con Edison [Member] | Derivatives Liabilities [Member] | Fair Value Of Derivative Liabilities, Current [Member]
Derivatives And Hedging Activities [Line Items]
Current Fair value of derivative liabilities	149	331
Con Edison [Member] | Derivatives Liabilities [Member] | Fair Value Of Derivative Liabilities, Long-Term [Member]
Derivatives And Hedging Activities [Line Items]
Current Fair value of derivative liabilities	53	83
CECONY [Member] | Derivatives Assets [Member]
Derivatives And Hedging Activities [Line Items]
Current Other current assets	40	30
Impact of netting	(13)	(6)
Net derivative assets	27	24
CECONY [Member] | Derivatives Assets [Member] | Other Current Assets [Member]
Derivatives And Hedging Activities [Line Items]
Current Other current assets	30	16
CECONY [Member] | Derivatives Assets [Member] | Other Deferred Charges And Non-Current Assets [Member]
Derivatives And Hedging Activities [Line Items]
Current Other current assets	10	14
CECONY [Member] | Derivatives Liabilities [Member]
Derivatives And Hedging Activities [Line Items]
Current Fair value of derivative liabilities	88	175
Impact of netting	(46)	(53)
Net derivative liabilities	42	122
CECONY [Member] | Derivatives Liabilities [Member] | Fair Value Of Derivative Liabilities, Current [Member]
Derivatives And Hedging Activities [Line Items]
Current Fair value of derivative liabilities	60	127
CECONY [Member] | Derivatives Liabilities [Member] | Fair Value Of Derivative Liabilities, Long-Term [Member]
Derivatives And Hedging Activities [Line Items]
Current Fair value of derivative liabilities	$ 28	$ 48

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Consolidated Income Statement (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
OPERATING REVENUES
Electric	$ 2,810	$ 2,861	$ 6,762	$ 6,883
Gas	216	220	1,161	1,309
Steam	68	76	414	508
Non-utility	344	472	950	1,272
TOTAL OPERATING REVENUES	3,438	3,629	9,287	9,972
OPERATING EXPENSES
Purchased power	930	1,239	2,440	3,124
Fuel	59	73	213	317
Gas purchased for resale	56	73	314	491
Operations and maintenance	826	783	2,365	2,213
Depreciation and amortization	240	222	709	659
Taxes, other than income taxes	476	483	1,360	1,387
TOTAL OPERATING EXPENSES	2,587	2,873	7,401	8,191
OPERATING INCOME	851	756	1,886	1,781
OTHER INCOME (DEDUCTIONS)
Investment and other income	4		14	19
Allowance for equity funds used during construction	1	2	3	8
Other deductions	(3)	(3)	(13)	(14)
TOTAL OTHER INCOME (DEDUCTIONS)	2	(1)	4	13
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	853	755	1,890	1,794
INTEREST EXPENSE
Interest on long-term debt	146	145	440	437
Other interest	6		17	15
Allowance for borrowed funds used during construction		(1)	(2)	(4)
NET INTEREST EXPENSE	152	144	455	448
INCOME BEFORE INCOME TAX EXPENSE	701	611	1,435	1,346
INCOME TAX EXPENSE	261	225	501	477
NET INCOME	440	386	934	869
Preferred stock dividend requirements of subsidiary		(3)	(3)	(9)
NET INCOME FOR COMMON STOCK	440	383	931	860
Net income for common stock per common share-basic	$ 1.50	$ 1.31	$ 3.18	$ 2.94
Net income for common stock per common share-diluted	$ 1.49	$ 1.30	$ 3.16	$ 2.92
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK	$ 0.605	$ 0.600	$ 1.815	$ 1.800
AVERAGE NUMBER OF SHARES OUTSTANDING-BASIC (IN MILLIONS)	292.9	292.9	292.9	292.5
AVERAGE NUMBER OF SHARES OUTSTANDING-DILUTED (IN MILLIONS)	294.6	294.6	294.6	294.2
CECONY [Member]
OPERATING REVENUES
Electric	2,611	2,644	6,307	6,378
Gas	189	197	1,017	1,156
Steam	68	76	414	508
TOTAL OPERATING REVENUES	2,868	2,917	7,738	8,042
OPERATING EXPENSES
Purchased power	604	736	1,554	1,840
Fuel	59	73	213	317
Gas purchased for resale	45	57	264	412
Other operations and maintenance	725	678	2,065	1,906
Depreciation and amortization	225	209	664	618
Taxes, other than income taxes	456	462	1,300	1,330
TOTAL OPERATING EXPENSES	2,114	2,215	6,060	6,423
OPERATING INCOME	754	702	1,678	1,619
OTHER INCOME (DEDUCTIONS)
Investment and other income	2	(6)	6	3
Allowance for equity funds used during construction		1	2	6
Other deductions	(2)	(3)	(10)	(12)
TOTAL OTHER INCOME (DEDUCTIONS)		(8)	(2)	(3)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	754	694	1,676	1,616
INTEREST EXPENSE
Interest on long-term debt	130	130	395	393
Other interest	8	4	19	13
Allowance for borrowed funds used during construction		(1)	(1)	(3)
NET INTEREST EXPENSE	138	133	413	403
INCOME BEFORE INCOME TAX EXPENSE	616	561	1,263	1,213
INCOME TAX EXPENSE	227	205	436	425
NET INCOME	389	356	827	788
Preferred stock dividend requirements of subsidiary		(3)	(3)	(9)
NET INCOME FOR COMMON STOCK	$ 389	$ 353	$ 824	$ 779

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Environmental Matters - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2010
CECONY [Member] | Asbestos Proceeding [Member]
Accrued Environmental Remediation Costs [Line Items]
Estimated undiscounted asbestos liability	$ 10
Estimated undiscounted asbestos liability in year	15 years
CECONY [Member] | Superfund Sites [Member] | Environmental Remediation Expense [Member] | Manufactured Gas Plant Sites Member] | Other Manufactured Gas Plant-Related Environmental Contaminants [Member]
Accrued Environmental Remediation Costs [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants	1,900.0
O&R [Member] | Superfund Sites [Member] | Environmental Remediation Expense [Member] | Manufactured Gas Plant Sites Member]
Accrued Environmental Remediation Costs [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants	$ 200.0

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Consolidated Balance Sheet (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $25 and $24 in 2012 and 2011, respectively	$ 99	$ 89
Construction work in progress	400	39
NET PLANT	26,324	25,093
OTHER NONCURRENT ASSETS
Goodwill	429	429
Intangible assets, less accumulated amortization of $3 in 2012 and 2011	3	3
Regulatory assets	8,897	9,337
Other deferred charges and noncurrent assets	278	259
TOTAL OTHER NONCURRENT ASSETS	9,607	10,028
TOTAL ASSETS	39,633	39,214
CURRENT ASSETS
Cash and temporary cash investments	69	648
Accounts receivable - customers, less allowance for uncollectible accounts of $79 in 2012 and 2011	1,319	1,123
Other receivables	216	303
Accrued unbilled revenue	451	474
Fuel oil, gas in storage, materials and supplies, at average cost	355	356
Prepayments	433	145
Regulatory assets	77	164
Deferred tax assets - current	113	266
Other current assets	207	159
TOTAL CURRENT ASSETS	3,240	3,638
INVESTMENTS	462	455
UTILITY PLANT, AT ORIGINAL COST
General	2,253	1,944
TOTAL	31,315	29,775
Less: Accumulated depreciation	6,388	6,051
Net	24,927	23,724
Construction work in progress	898	1,241
NET UTILITY PLANT	25,825	24,965
CURRENT LIABILITIES
Long-term debt due within one year	930	530
Notes payable	340
Accounts payable	968	955
Customer deposits	308	303
Accrued taxes	108	188
Accrued interest	206	160
Accrued wages	88	91
Fair value of derivative liabilities	56	169
Regulatory liabilities	231	118
Other current liabilities	489	473
TOTAL CURRENT LIABILITIES	3,724	2,987
NONCURRENT LIABILITIES
Obligations under capital leases	2	2
Provision for injuries and damages	145	181
Pensions and retiree benefits	4,039	4,835
Superfund and other environmental costs	537	489
Asset retirement obligations	149	145
Fair value of derivative liabilities	34	48
Other noncurrent liabilities	124	131
TOTAL NONCURRENT LIABILITIES	5,030	5,831
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	8,026	7,563
Regulatory liabilities	1,102	977
Other deferred credits	70	64
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	9,198	8,604
LONG-TERM DEBT	9,839	10,143
SHAREHOLDER'S EQUITY
Common shareholder's equity (See Statement of Common Shareholder's Equity)	11,842	11,436
Preferred stock of subsidiary		213
TOTAL SHAREHOLDER'S EQUITY	11,842	11,649
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	39,633	39,214
CECONY [Member]
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $25 and $24 in 2012 and 2011, respectively	4	6
NET PLANT	24,311	23,502
OTHER NONCURRENT ASSETS
Regulatory assets	8,285	8,661
Other deferred charges and noncurrent assets	241	217
TOTAL OTHER NONCURRENT ASSETS	8,526	8,878
TOTAL ASSETS	35,699	35,218
CURRENT ASSETS
Cash and temporary cash investments	26	372
Accounts receivable - customers, less allowance for uncollectible accounts of $79 in 2012 and 2011	1,174	977
Other receivables	103	102
Accrued unbilled revenue	347	366
Accounts receivable from affiliated companies	82	54
Fuel oil, gas in storage, materials and supplies, at average cost	296	308
Prepayments	393	85
Regulatory assets	62	140
Deferred tax assets - current	62	157
Other current assets	114	100
TOTAL CURRENT ASSETS	2,659	2,661
INVESTMENTS	203	177
UTILITY PLANT, AT ORIGINAL COST
General	2,081	1,785
TOTAL	29,291	27,854
Less: Accumulated depreciation	5,834	5,523
Net	23,457	22,331
Construction work in progress	850	1,165
NET UTILITY PLANT	24,307	23,496
CURRENT LIABILITIES
Long-term debt due within one year	925	525
Notes payable	332
Accounts payable	772	774
Accounts payable to affiliated companies	22	16
Customer deposits	295	290
Accrued taxes	33	32
Accrued taxes to affiliated companies	165	126
Accrued interest	179	133
Accrued wages	83	81
Fair value of derivative liabilities	30	98
Regulatory liabilities	199	79
Other current liabilities	400	396
TOTAL CURRENT LIABILITIES	3,435	2,550
NONCURRENT LIABILITIES
Obligations under capital leases	2	2
Provision for injuries and damages	138	173
Pensions and retiree benefits	3,627	4,337
Superfund and other environmental costs	423	373
Asset retirement obligations	148	145
Fair value of derivative liabilities	12	24
Other noncurrent liabilities	116	120
TOTAL NONCURRENT LIABILITIES	4,466	5,174
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	7,301	6,921
Regulatory liabilities	978	861
Other deferred credits	67	61
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	8,346	7,843
LONG-TERM DEBT	8,920	9,220
SHAREHOLDER'S EQUITY
Common shareholder's equity (See Statement of Common Shareholder's Equity)	10,532	10,218
Preferred stock of subsidiary		213
TOTAL SHAREHOLDER'S EQUITY	10,532	10,431
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	35,699	35,218
Electric Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	22,019	21,114
Electric Transmission [Member] | CECONY [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	20,728	19,886
Gas Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	5,009	4,734
Gas Transmission [Member] | CECONY [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	4,448	4,200
Steam Plant [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,034	1,983
Steam Plant [Member] | CECONY [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,034	$ 1,983

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Fair Value Measurements - Reconciliation Of Beginning And Ending Net Balances For Assets And Liabilities Measured At Level 3 Fair Value (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012		Sep. 30, 2011
Con Edison [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ (61)	$ 71	$ 29		$ 3
Included in Earnings	(15)	(41)	(95)		(62)
Included in Regulatory Assets and Liabilities	19	7	14		54
Purchases	7	8	18		22
Issuances
Sales
Settlements	25	15	107		38
Transfer In/Out of Level 3	22	24	(76)		29
Ending Balance	(3)	84	(3)		84
Con Edison [Member] | Commodity [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance		(25)	(62)		(88)
Included in Earnings		(37)	(97)		(59)
Included in Regulatory Assets and Liabilities		9	11		54
Purchases		8	18		22
Issuances
Sales
Settlements		14	106		35
Transfer In/Out of Level 3		24	21		29
Ending Balance	(3)	(7)	(3)		(7)
Con Edison [Member] | Interest Rate Contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance		(10)	(8)		(10)
Included in Earnings		(1)	(1)		(3)
Included in Regulatory Assets and Liabilities		1			1
Issuances
Sales
Settlements		1	1		3
Transfer In/Out of Level 3			8	[1]
Ending Balance		(9)			(9)
Con Edison [Member] | Other Assets [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance		106	99	[2]	101
Included in Earnings		(3)	3	[2]
Included in Regulatory Assets and Liabilities		(3)	3	[2]	(1)
Issuances				[2]
Sales				[2]
Transfer In/Out of Level 3			(105)	[1],[2]
Ending Balance		100			100
CECONY [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	(10)	96	83		66
Included in Earnings	(9)	(11)	(22)		(11)
Included in Regulatory Assets and Liabilities	8	(1)	10		21
Purchases	7	8	15		18
Issuances
Sales
Settlements	5	3	12		(4)
Transfer In/Out of Level 3	11	9	(86)		14
Ending Balance	12	104	12		104
CECONY [Member] | Commodity [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance			(7)		(26)
Included in Earnings		(8)	(25)		(11)
Included in Regulatory Assets and Liabilities		1	8		22
Purchases		8	15		18
Issuances
Sales
Settlements		3	12		(4)
Transfer In/Out of Level 3		9	9	[1]	14
Ending Balance	12	13	12		13
CECONY [Member] | Other Assets [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance		96	90	[2]	92
Included in Earnings		(3)	3	[2]
Included in Regulatory Assets and Liabilities		(2)	2	[2]	(1)
Issuances				[2]
Sales				[2]
Transfer In/Out of Level 3			(95)	[1],[2]
Ending Balance		$ 91			$ 91

[1] Other assets and interest rate contract were transferred as of March 31, 2012.

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

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Regulatory Matters - Regulatory Assets and Liabilities (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Regulatory Assets [Line Items]
Regulatory assets - long-term	$ 8,897	$ 9,337
Regulatory assets - current	77	164
Regulatory liabilities - long-term	1,102	977
Regulatory liabilities - current	231	118
Con Edison [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	8,897	9,337
Regulatory assets - current	77	164
Regulatory liabilities - long-term	1,102	977
Total Regulatory Assets	8,974	9,501
Regulatory liabilities - current	231	118
Total Regulatory Liabilities	1,333	1,095
Con Edison [Member] | Unrecognized Pension And Other Postretirement Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	5,211	5,852
Con Edison [Member] | Future Income Tax [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	1,888	1,798
Con Edison [Member] | Environmental Restoration Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	722	681
Con Edison [Member] | Pension And Other Post Retirement Benefits Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	205	198
Con Edison [Member] | Revenue Taxes [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	177	163
Con Edison [Member] | Surcharge For New York State Assessment [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	135	90
Con Edison [Member] | Deferred Storm Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	120	128
Con Edison [Member] | Net Electric Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	107	121
Con Edison [Member] | Deferred Derivative Losses - Long-Term [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	47	60
Regulatory assets - current	75	164
Con Edison [Member] | O&R Transition Bond Charges [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	40	44
Con Edison [Member] | Preferred Stock Redemption [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	29
Con Edison [Member] | Workers' Compensation [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	19	23
Con Edison [Member] | Property Tax Reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	15	13
Regulatory liabilities - long-term	137	35
Con Edison [Member] | Recoverable Energy Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	1	14
Regulatory assets - current	2
Con Edison [Member] | Other [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	181	152
Con Edison [Member] | Allowance For Cost Of Removal Less Salvage [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	488	448
Con Edison [Member] | Net Unbilled Revenue Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	121	104
Con Edison [Member] | World Trade Center Settlement Proceeds [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	62	62
Con Edison [Member] | Long-Term Interest Rate Reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	54	30
Con Edison [Member] | Carrying Charges On Transmission And Distribution Net Plant [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	36	38
Con Edison [Member] | Expenditure Prudence Proceeding [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	15	11
Con Edison [Member] | Gas Line Losses [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	14	21
Con Edison [Member] | Energy Efficiency Programs [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	5	22
Con Edison [Member] | Other Liabilities [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	170	206
Con Edison [Member] | Revenue Decoupling Mechanism [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	107	66
Con Edison [Member] | Electric Surcharge Offset [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	60
Con Edison [Member] | Refundable Energy Costs - Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	58	51
Con Edison [Member] | Deferred Derivative Gains, Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	6	1
CECONY [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	8,285	8,661
Regulatory assets - current	62	140
Regulatory liabilities - long-term	978	861
Total Regulatory Assets	8,347	8,801
Regulatory liabilities - current	199	79
Total Regulatory Liabilities	1,177	940
CECONY [Member] | Unrecognized Pension And Other Postretirement Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	4,972	5,554
CECONY [Member] | Future Income Tax [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	1,810	1,724
CECONY [Member] | Environmental Restoration Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	607	564
CECONY [Member] | Pension And Other Post Retirement Benefits Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	174	157
CECONY [Member] | Revenue Taxes [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	171	158
CECONY [Member] | Surcharge For New York State Assessment [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	125	82
CECONY [Member] | Deferred Storm Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	78	80
CECONY [Member] | Net Electric Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	107	121
CECONY [Member] | Deferred Derivative Losses - Long-Term [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	25	44
Regulatory assets - current	62	140
CECONY [Member] | Preferred Stock Redemption [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	29
CECONY [Member] | Workers' Compensation [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	19	23
CECONY [Member] | Property Tax Reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	137	35
CECONY [Member] | Recoverable Energy Costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	1	14
CECONY [Member] | Other [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	167	140
CECONY [Member] | Allowance For Cost Of Removal Less Salvage [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	407	372
CECONY [Member] | Net Unbilled Revenue Deferrals [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	121	104
CECONY [Member] | World Trade Center Settlement Proceeds [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	62	62
CECONY [Member] | Long-Term Interest Rate Reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	54	30
CECONY [Member] | Carrying Charges On Transmission And Distribution Net Plant [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	16	14
CECONY [Member] | Expenditure Prudence Proceeding [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	15	11
CECONY [Member] | Gas Line Losses [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	14	21
CECONY [Member] | Energy Efficiency Programs [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	5	20
CECONY [Member] | Other Liabilities [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	147	192
CECONY [Member] | Revenue Decoupling Mechanism [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	103	66
CECONY [Member] | Electric Surcharge Offset [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	60
CECONY [Member] | Refundable Energy Costs - Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	30	12
CECONY [Member] | Deferred Derivative Gains, Current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	$ 6	$ 1

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2012

Earnings Per Common Share

Earnings Per Common Share

For the three and nine months ended September 30, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2012		2011
Net income for common stock		$   440		$   383		$   931		$   860
Weighted average common shares outstanding – basic		292.9		292.9		292.9		292.5
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.7		1.7		1.7
Adjusted weighted average common shares outstanding – diluted		294.6		294.6		294.6		294.2
Net income for common stock per common share – basic		$  1.50		$  1.31		$  3.18		$  2.94
Net income for common stock per common share – diluted		$  1.49		$  1.30		$  3.16		$  2.92

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Capitalization - Additional Information (Detail) (USD $)					1 Months Ended			1 Months Ended
	Sep. 30, 2012 Consolidated Edison Inc [Member]	Dec. 31, 2011 Consolidated Edison Inc [Member]	Sep. 30, 2012 Consolidated Edison Inc [Member] Level 2 [Member]	Sep. 30, 2012 Consolidated Edison Inc [Member] Level 3 [Member]	Mar. 31, 2012 CECONY [Member]	Sep. 30, 2012 CECONY [Member]	Dec. 31, 2011 CECONY [Member]	Nov. 30, 2012 CECONY [Member] Subsequent Event [Member]	Sep. 30, 2012 CECONY [Member] Level 2 [Member]	Sep. 30, 2012 CECONY [Member] Level 3 [Member]
Issue of debentures					$ 400,000,000
Rate of debentures					4.20%
Period of debentures					30 years
Net proceeds from the sale					239,000,000
Redemption of Cumulative Preferred Stock					5
Cumulative Preferred Stock, par value					$ 100
Tax-exempt debt								225,000,000
Fair values of long-term debt	$ 13,197,000,000	$ 12,744,000,000	$ 12,561,000,000	$ 636,000,000		$ 12,001,000,000	$ 11,593,000,000		$ 11,365,000,000	$ 636,000,000

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Regulatory Matters (Tables)

9 Months Ended

Sep. 30, 2012

Regulatory Assets and Liabilities

Regulatory assets and liabilities at September 30, 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		$5,211		$5,852		$4,972		$5,554
Future income tax		1,888		1,798		1,810		1,724
Environmental remediation costs		722		681		607		564
Pension and other post retirement benefits deferrals		205		198		174		157
Revenue taxes		177		163		171		158
Surcharge for New York State assessment		135		90		125		82
Deferred storm costs		120		128		78		80
Net electric deferrals		107		121		107		121
Deferred derivative losses – long-term		47		60		25		44
O&R transition bond charges		40		44		—		—
Preferred stock redemption		29		—		29		—
Workers’ compensation		19		23		19		23
Property tax reconciliation		15		13		—		—
Recoverable energy costs – long-term		1		14		1		14
Other		181		152		167		140
Regulatory assets – long-term		8,897		9,337		8,285		8,661
Deferred derivative losses – current		75		164		62		140
Recoverable energy costs – current		2		—		—		—
Regulatory assets – current		77		164		62		140
Total Regulatory Assets		$8,974		$9,501		$8,347		$8,801
Regulatory liabilities
Allowance for cost of removal less salvage		$   488		$   448		$   407		$   372
Property tax reconciliation		137		35		137		35
Net unbilled revenue deferrals		121		104		121		104
World Trade Center settlement proceeds		62		62		62		62
Long-term interest rate reconciliation		54		30		54		30
Carrying charges on transmission and distribution net plant		36		38		16		14
Expenditure prudence proceeding		15		11		15		11
Gas line losses		14		21		14		21
Energy efficiency programs		5		22		5		20
Other		170		206		147		192
Regulatory liabilities – long-term		1,102		977		978		861
Revenue decoupling mechanism		107		66		103		66
Electric surcharge offset		60		—		60		—
Refundable energy costs – current		58		51		30		12
Deferred derivative gains – current		6		1		6		1
Regulatory liabilities – current		231		118		199		79
Total Regulatory Liabilities		$1,333		$1,095		$1,177		$   940

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Consolidated Balance Sheet (Parenthetical) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Accounts receivable - customers, allowance for uncollectible accounts	$ 85	$ 87
Other receivables, allowance for uncollectible accounts	10	10
Non-utility property, accumulated depreciation	66	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	$ 25	$ 24

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Consolidated Statement Of Comprehensive Income (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Net Income	$ 440	$ 386	$ 934	$ 869
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension plan liability adjustments, net of $(1) taxes in 2012	2	2	8	7
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	2	2	8	7
COMPREHENSIVE INCOME	442	388	942	876
Preferred stock dividend requirements of subsidiary		(3)	(3)	(9)
COMPREHENSIVE INCOME FOR COMMON STOCK	442	385	939	867
CECONY [Member]
Net Income	389	356	827	788
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension plan liability adjustments, net of $(1) taxes in 2012			(2)
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES			(2)
COMPREHENSIVE INCOME	389	356	825	788
Preferred stock dividend requirements of subsidiary		$ (3)

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Other Material Contingencies

9 Months Ended

Sep. 30, 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 $(73) million at September 30, 2012 and $(55) million at December 31, 2011 and is comprised of a $228 million gross investment less $301 million of deferred tax liabilities at September 30, 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. Oral argument on the appeal is scheduled to be held in November 2012.

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 2011, 2010, 2009 and 2008, the IRS has disallowed $35 million, $40 million, $41 million and $42 million, respectively, of net tax deductions taken with respect to both of the LILO transactions. When these audit level disallowances become appealable, Con Edison intends to file an appeal of the disallowances.

Con Edison believes that its LILO transactions have been correctly reported, and has not recorded any reserve with respect to the disallowance of tax losses, or related interest, in connection with its LILO transactions. Con Edison’s estimated tax savings, reflected in its financial statements, from the two LILO transactions through September 30, 2012, in the aggregate, was $248 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 $122 million net of tax at September 30, 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 $823 million and $760 million at September 30, 2012 and December 31, 2011, respectively.

A summary, by type and term, of Con Edison’s total guarantees at September 30, 2012 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions		$696		$2		$66		$764
Intra-company guarantees		15		—		1		16
Other guarantees		38		5		—		43
TOTAL		$749		$7		$67		$823

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;

• $11 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 September 30, 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 $(73) million at September 30, 2012 and $(55) million at December 31, 2011 and is comprised of a $228 million gross investment less $301 million of deferred tax liabilities at September 30, 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. Oral argument on the appeal is scheduled to be held in November 2012.

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 2011, 2010, 2009 and 2008, the IRS has disallowed $35 million, $40 million, $41 million and $42 million, respectively, of net tax deductions taken with respect to both of the LILO transactions. When these audit level disallowances become appealable, Con Edison intends to file an appeal of the disallowances.

Con Edison believes that its LILO transactions have been correctly reported, and has not recorded any reserve with respect to the disallowance of tax losses, or related interest, in connection with its LILO transactions. Con Edison’s estimated tax savings, reflected in its financial statements, from the two LILO transactions through September 30, 2012, in the aggregate, was $248 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 $122 million net of tax at September 30, 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 $823 million and $760 million at September 30, 2012 and December 31, 2011, respectively.

A summary, by type and term, of Con Edison’s total guarantees at September 30, 2012 is as follows:

Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions		$696		$2		$66		$764
Intra-company guarantees		15		—		1		16
Other guarantees		38		5		—		43
TOTAL		$749		$7		$67		$823

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;

• $11 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 September 30, 2012.

XML

Document and Entity Information	9 Months Ended
	Sep. 30, 2012	Oct. 31, 2012
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q3
Trading Symbol	ED
Entity Registrant Name	CONSOLIDATED EDISON INC
Entity Central Index Key	0001047862
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		292,872,896
Consolidated Edison Co Of New York Inc [Member]
Entity Information [Line Items]
Entity Registrant Name	CONSOLIDATED EDISON CO OF NEW YORK INC
Entity Central Index Key	0000023632
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

XML

Financial Information by Business Segment

9 Months Ended

Sep. 30, 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 September 30,
	Operating revenues					Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012		2011			2012			2011			2012		2011		2012			2011
CECONY
Electric		$2,611		$2,644			$    4			$    3			$179		$166		$812			$758
Gas		189		197			1			1			31		28		(21	)		(23	)
Steam		68		76			20			20			15		15		(37	)		(33	)
Consolidation adjustments		—		—			(25	)		(24	)		—		—		—			—
Total CECONY		$2,868		$2,917			$  —			$  —			$225		$209		$754			$702
O&R
Electric		$   199		$   217			$  —			$  —			$  10		$    9		$  50			$  44
Gas		27		24			—			—			3		3		(6	)		(6	)
Total O&R		$   226		$   241			$  —			$  —			$  13		$  12		$  44			$  38
Competitive energy businesses		$   344		$   472			$    2			$    3			$    2		$    1		$  53			$  16
Other*		—		(1	)		(2	)		(3	)		—		—		—			—
Total Con Edison		$3,438		$3,629			$  —			$  —			$240		$222		$851			$756

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

	For the Nine Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012			2011			2012			2011			2012		2011		2012			2011
CECONY
Electric		$6,307			$6,378			$  11			$    9			$527		$489		$1,383			$1,326
Gas		1,017			1,156			4			4			89		82		255			212
Steam		414			508			58			59			48		47		40			81
Consolidation adjustments		—			—			(73	)		(72	)		—		—		—			—
Total CECONY		$7,738			$8,042			$  —			$  —			$664		$618		$1,678			$1,619
O&R
Electric		$   457			$   507			$  —			$  —			$  28		$  26		$     74			$     69
Gas		144			153			—			—			11		10		26			22
Total O&R		$   601			$   660			$  —			$  —			$  39		$  36		$   100			$     91
Competitive energy businesses		$   954			$1,286			$    6			$    9			$    6		$    5		$   111			$     75
Other*		(6	)		(16	)		(6	)		(9	)		—		—		(3	)		(4	)
Total Con Edison		$9,287			$9,972			$  —			$  —			$709		$659		$1,886			$1,781

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

In July 2012, Con Edison Development purchased a company that is developing 70 MW (AC) of solar energy projects in Alpaugh, California (Alpaugh). Electricity generated by the projects is to be purchased by Pacific Gas and Electric Company pursuant to long-term power purchase agreements (PPA). Alpaugh was purchased for $288 million, including contingent consideration of $2 million, of which $284 million has been allocated to construction work in progress and $4 million to deposits relating to the PPA and interconnection agreements. The total cost to acquire and construct these projects is estimated to be $350 million.

In October 2012, Con Edison Development purchased two companies that are developing 40 MW (AC) of solar energy projects in Tulare and Kings County, California. Electricity generated by the projects is to be purchased by Pacific Gas and Electric Company pursuant to long-term PPAs. The projects were purchased for approximately $51 million, of which $39 million has been allocated to construction work in progress and $12 million to deposits relating to the PPA and interconnection agreements. The total cost to acquire and construct these projects is estimated to be $200 million.

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 September 30,
	Operating revenues					Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012		2011			2012			2011			2012		2011		2012			2011
CECONY
Electric		$2,611		$2,644			$    4			$    3			$179		$166		$812			$758
Gas		189		197			1			1			31		28		(21	)		(23	)
Steam		68		76			20			20			15		15		(37	)		(33	)
Consolidation adjustments		—		—			(25	)		(24	)		—		—		—			—
Total CECONY		$2,868		$2,917			$  —			$  —			$225		$209		$754			$702
O&R
Electric		$   199		$   217			$  —			$  —			$  10		$    9		$  50			$  44
Gas		27		24			—			—			3		3		(6	)		(6	)
Total O&R		$   226		$   241			$  —			$  —			$  13		$  12		$  44			$  38
Competitive energy businesses		$   344		$   472			$    2			$    3			$    2		$    1		$  53			$  16
Other*		—		(1	)		(2	)		(3	)		—		—		—			—
Total Con Edison		$3,438		$3,629			$  —			$  —			$240		$222		$851			$756

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

	For the Nine Months Ended September 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
(Millions of Dollars)	2012			2011			2012			2011			2012		2011		2012			2011
CECONY
Electric		$6,307			$6,378			$  11			$    9			$527		$489		$1,383			$1,326
Gas		1,017			1,156			4			4			89		82		255			212
Steam		414			508			58			59			48		47		40			81
Consolidation adjustments		—			—			(73	)		(72	)		—		—		—			—
Total CECONY		$7,738			$8,042			$  —			$  —			$664		$618		$1,678			$1,619
O&R
Electric		$   457			$   507			$  —			$  —			$  28		$  26		$     74			$     69
Gas		144			153			—			—			11		10		26			22
Total O&R		$   601			$   660			$  —			$  —			$  39		$  36		$   100			$     91
Competitive energy businesses		$   954			$1,286			$    6			$    9			$    6		$    5		$   111			$     75
Other*		(6	)		(16	)		(6	)		(9	)		—		—		(3	)		(4	)
Total Con Edison		$9,287			$9,972			$  —			$  —			$709		$659		$1,886			$1,781

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

In July 2012, Con Edison Development purchased a company that is developing 70 MW (AC) of solar energy projects in Alpaugh, California (Alpaugh). Electricity generated by the projects is to be purchased by Pacific Gas and Electric Company pursuant to long-term power purchase agreements (PPA). Alpaugh was purchased for $288 million, including contingent consideration of $2 million, of which $284 million has been allocated to construction work in progress and $4 million to deposits relating to the PPA and interconnection agreements. The total cost to acquire and construct these projects is estimated to be $350 million.

In October 2012, Con Edison Development purchased two companies that are developing 40 MW (AC) of solar energy projects in Tulare and Kings County, California. Electricity generated by the projects is to be purchased by Pacific Gas and Electric Company pursuant to long-term PPAs. The projects were purchased for approximately $51 million, of which $39 million has been allocated to construction work in progress and $12 million to deposits relating to the PPA and interconnection agreements. The total cost to acquire and construct these projects is estimated to be $200 million.

XML

Consolidated Statement Of Comprehensive Income (Parenthetical) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Pension plan liability adjustments, taxes	$ (1)	$ 1	$ 5	$ 4
CECONY [Member]
Pension plan liability adjustments, taxes	$ (1)		$ (1)

XML

Capitalization

9 Months Ended

Sep. 30, 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). In November 2012, CECONY purchased $225 million of its tax-exempt debt that was subject to mandatory tender.

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

(Millions of Dollars)	September 30, 2012				December 31, 2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison		$10,769		$13,197		$10,673		$12,744
CECONY		$  9,845		$12,001		$  9,745		$11,593

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,561 million and $636 million of the fair value of long-term debt at September 30, 2012 are classified as Level 2 and Level 3, respectively. For CECONY, $11,365 million and $636 million of the fair value of long-term debt at September 30, 2012 are classified as Level 2 and Level 3, respectively (see Note K). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

CECONY [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). In November 2012, CECONY purchased $225 million of its tax-exempt debt that was subject to mandatory tender.

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

(Millions of Dollars)	September 30, 2012				December 31, 2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison		$10,769		$13,197		$10,673		$12,744
CECONY		$  9,845		$12,001		$  9,745		$11,593

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,561 million and $636 million of the fair value of long-term debt at September 30, 2012 are classified as Level 2 and Level 3, respectively. For CECONY, $11,365 million and $636 million of the fair value of long-term debt at September 30, 2012 are classified as Level 2 and Level 3, respectively (see Note K). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

XML

Regulatory Matters

9 Months Ended

Sep. 30, 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 the NYSPSC approved in June 2012, 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 is being 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 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, property taxes and certain other expenses are reconciled to amounts for those expenses 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 September 30, 2012, the company had collected an estimated $1,031 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. These estimated potential overcharges related to transactions that involved certain employees who were arrested and a contractor that performed work for the company. The company expects that the NYSPSC’s consultant will be reporting an estimate of potential overcharges with respect to a substantial portion of the company’s construction expenditures from January 2000 to January 2009, including expenditures for transactions that did not involve the arrested employees and contractor. The NYSPSC consultant’s estimate is expected to be materially higher than its $21 million provisional assessment. The NYSPSC’s consultant is developing its estimate based on its review of a selection of the construction expenditures and its extrapolation of the results of its review (which the company is disputing). The NYSPSC’s consultant is expected to continue to review the company’s expenditures. At September 30, 2012, the company had a $15 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 September 30, 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		$5,211		$5,852		$4,972		$5,554
Future income tax		1,888		1,798		1,810		1,724
Environmental remediation costs		722		681		607		564
Pension and other post retirement benefits deferrals		205		198		174		157
Revenue taxes		177		163		171		158
Surcharge for New York State assessment		135		90		125		82
Deferred storm costs		120		128		78		80
Net electric deferrals		107		121		107		121
Deferred derivative losses – long-term		47		60		25		44
O&R transition bond charges		40		44		—		—
Preferred stock redemption		29		—		29		—
Workers’ compensation		19		23		19		23
Property tax reconciliation		15		13		—		—
Recoverable energy costs – long-term		1		14		1		14
Other		181		152		167		140
Regulatory assets – long-term		8,897		9,337		8,285		8,661
Deferred derivative losses – current		75		164		62		140
Recoverable energy costs – current		2		—		—		—
Regulatory assets – current		77		164		62		140
Total Regulatory Assets		$8,974		$9,501		$8,347		$8,801
Regulatory liabilities
Allowance for cost of removal less salvage		$   488		$   448		$   407		$   372
Property tax reconciliation		137		35		137		35
Net unbilled revenue deferrals		121		104		121		104
World Trade Center settlement proceeds		62		62		62		62
Long-term interest rate reconciliation		54		30		54		30
Carrying charges on transmission and distribution net plant		36		38		16		14
Expenditure prudence proceeding		15		11		15		11
Gas line losses		14		21		14		21
Energy efficiency programs		5		22		5		20
Other		170		206		147		192
Regulatory liabilities – long-term		1,102		977		978		861
Revenue decoupling mechanism		107		66		103		66
Electric surcharge offset		60		—		60		—
Refundable energy costs – current		58		51		30		12
Deferred derivative gains – current		6		1		6		1
Regulatory liabilities – current		231		118		199		79
Total Regulatory Liabilities		$1,333		$1,095		$1,177		$   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 the NYSPSC approved in June 2012, 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 is being 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 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, property taxes and certain other expenses are reconciled to amounts for those expenses 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 September 30, 2012, the company had collected an estimated $1,031 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. These estimated potential overcharges related to transactions that involved certain employees who were arrested and a contractor that performed work for the company. The company expects that the NYSPSC’s consultant will be reporting an estimate of potential overcharges with respect to a substantial portion of the company’s construction expenditures from January 2000 to January 2009, including expenditures for transactions that did not involve the arrested employees and contractor. The NYSPSC consultant’s estimate is expected to be materially higher than its $21 million provisional assessment. The NYSPSC’s consultant is developing its estimate based on its review of a selection of the construction expenditures and its extrapolation of the results of its review (which the company is disputing). The NYSPSC’s consultant is expected to continue to review the company’s expenditures. At September 30, 2012, the company had a $15 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 September 30, 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		$5,211		$5,852		$4,972		$5,554
Future income tax		1,888		1,798		1,810		1,724
Environmental remediation costs		722		681		607		564
Pension and other post retirement benefits deferrals		205		198		174		157
Revenue taxes		177		163		171		158
Surcharge for New York State assessment		135		90		125		82
Deferred storm costs		120		128		78		80
Net electric deferrals		107		121		107		121
Deferred derivative losses – long-term		47		60		25		44
O&R transition bond charges		40		44		—		—
Preferred stock redemption		29		—		29		—
Workers’ compensation		19		23		19		23
Property tax reconciliation		15		13		—		—
Recoverable energy costs – long-term		1		14		1		14
Other		181		152		167		140
Regulatory assets – long-term		8,897		9,337		8,285		8,661
Deferred derivative losses – current		75		164		62		140
Recoverable energy costs – current		2		—		—		—
Regulatory assets – current		77		164		62		140
Total Regulatory Assets		$8,974		$9,501		$8,347		$8,801
Regulatory liabilities
Allowance for cost of removal less salvage		$   488		$   448		$   407		$   372
Property tax reconciliation		137		35		137		35
Net unbilled revenue deferrals		121		104		121		104
World Trade Center settlement proceeds		62		62		62		62
Long-term interest rate reconciliation		54		30		54		30
Carrying charges on transmission and distribution net plant		36		38		16		14
Expenditure prudence proceeding		15		11		15		11
Gas line losses		14		21		14		21
Energy efficiency programs		5		22		5		20
Other		170		206		147		192
Regulatory liabilities – long-term		1,102		977		978		861
Revenue decoupling mechanism		107		66		103		66
Electric surcharge offset		60		—		60		—
Refundable energy costs – current		58		51		30		12
Deferred derivative gains – current		6		1		6		1
Regulatory liabilities – current		231		118		199		79
Total Regulatory Liabilities		$1,333		$1,095		$1,177		$   940

XML

Summary of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2012

Earnings Per Common Share

For the three and nine months ended September 30, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2012		2011
Net income for common stock		$   440		$   383		$   931		$   860
Weighted average common shares outstanding – basic		292.9		292.9		292.9		292.5
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.7		1.7		1.7
Adjusted weighted average common shares outstanding – diluted		294.6		294.6		294.6		294.2
Net income for common stock per common share – basic		$  1.50		$  1.31		$  3.18		$  2.94
Net income for common stock per common share – diluted		$  1.49		$  1.30		$  3.16		$  2.92

XML

Derivative Instruments and Hedging Activities

9 Months Ended

Sep. 30, 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 September 30, 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		$(92	)		$(249	)		$(48	)		$(144	)
Impact of netting of cash collateral		59			110			33			46
Fair value of net derivative assets/(liabilities) – net		$(33	)		$(139	)		$(15	)		$  (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 September 30, 2012, Con Edison and CECONY had $118 million and $13 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $44 million with investment-grade counterparties, $25 million with commodity exchange brokers, $47 million with independent system operators and $2 million with non-rated counterparties. CECONY’s net credit exposure consisted of $3 million with investment-grade counterparties and $10 million with commodity exchange brokers.

Economic Hedges

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

The fair values of the Companies’ commodity derivatives at September 30, 2012 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets		$   91			$ 30
Long-term	Other deferred charges and non-current assets		19			10
Total derivative assets			$ 110			$ 40
Impact of netting			(59	)		(13	)
Net derivative assets			$   51			$ 27

Derivative Liabilities
Current	Fair value of derivative liabilities	$ 149		$ 60
Long-term	Fair value of derivative liabilities	53		28
Total derivative liabilities		$ 202		$ 88
Impact of netting		(118	)	(46	)
Net derivative liabilities		$   84		$ 42

(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
Derivative Assets
Current	Other current assets		$ 139			$  16
Long-term	Other deferred charges and non-current assets		26			14
Total derivative assets			$ 165			$  30
Impact of netting			(95	)		(6	)
Net derivative assets			$   70			$  24
Derivative Liabilities
Current	Fair value of derivative liabilities		$ 331			$127
Long-term	Fair value of derivative liabilities		83			48
Total derivative liabilities			$ 414			$175
Impact of netting			(205	)		(53	)
Net derivative liabilities			$ 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 tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2012:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended September 30, 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		$   5			$   5
Long-term	Deferred derivative gains		1			1
Total deferred gains/(losses)			$   6			$   6
Current	Deferred derivative losses		$ 51			$ 42
Current	Recoverable energy costs		(60	)		(52	)
Long-term	Deferred derivative losses		22			20
Total deferred gains/(losses)			$ 13			$ 10
Net deferred gains/(losses)			$ 19			$ 16
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$   9	(b)		$  —
	Gas purchased for resale		—			—
	Non-utility revenue		1	(b)		—
Total pre-tax gain/(loss) recognized in income			$ 10			$  —

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

(b) For the three months ended September 30, 2012, Con Edison recorded in purchased power expense an unrealized pre-tax gain/(loss) of $30 million.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 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		$     5			$     5
Long-term	Deferred derivative gains		1			1
Total deferred gains/(losses)			$     6			$     6
Current	Deferred derivative losses		$   89			$   78
Current	Recoverable energy costs		(187	)		(164	)
Long-term	Deferred derivative losses		13			19
Total deferred gains/(losses)			$  (85	)		$  (67	)
Net deferred gains/(losses)			$  (79	)		$  (61	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$  (49	)(b)		$    —
	Gas purchased for resale		(2	)		—
	Non-utility revenue		(11	)(b)		—
Total pre-tax gain/(loss) recognized in income			$  (62	)		$    —

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

(b) For the nine months ended September 30, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $75 million, respectively.

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

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

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

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

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains		$    —			$    —
Long-term	Regulatory liabilities		3			3
Total deferred gains/(losses)			$     3			$     3
Current	Deferred derivative losses		$   80			$   60
Current	Recoverable energy costs		(177	)		(134	)
Long-term	Regulatory assets		38			27
Total deferred gains/(losses)			$  (59	)		$  (47	)
Net deferred gains/(losses)			$  (56	)		$  (44	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$   81	(b)		$    —
	Gas purchased for resale		17			—
	Non-utility revenue		22	(b)		—
Total pre-tax gain/(loss) recognized in income			$ 120			$    —

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

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

As of September 30, 2012, Con Edison had 1,289 contracts, including 628 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)		MW-Months (b)		Number of Contracts (a)		dths (b)		Total Number of Contracts (a)
Con Edison		576		12,807,613		78		10,019		635		86,541,700		1,289
CECONY		113		3,271,000		—		—		515		81,080,000		628

(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 the clearing and settlement of derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statement of cash flows. Most derivative instrument contracts contain provisions that may require the Companies to provide collateral on derivative instruments in net liability positions. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the Companies’ credit ratings.

The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position and collateral posted at September 30, 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		$62			$41
Collateral posted		$14			$  9
Additional collateral (b) (downgrade one level from current ratings (c))		$ —			$ —
Additional collateral (b) (downgrade to below investment grade from current ratings (c))		$85	(d)		$45	(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 September 30, 2012, would have amounted to an estimated $25 million for Con Edison. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

(b) 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 September 30, 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 $27 million.

Interest Rate Swap

O&R has an interest rate swap pursuant to which it pays a fixed-rate of 6.09 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at September 30, 2012 was an unrealized loss of $6 million, which has been included in Con Edison’s consolidated balance sheet as a noncurrent liability/fair value of derivative liabilities and a regulatory asset. The increase in the fair value of the swap for the three and nine months ended September 30, 2012 was $1 million and $2 million, respectively. 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 September 30, 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		$(92	)		$(249	)		$(48	)		$(144	)
Impact of netting of cash collateral		59			110			33			46
Fair value of net derivative assets/(liabilities) – net		$(33	)		$(139	)		$(15	)		$  (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 September 30, 2012, Con Edison and CECONY had $118 million and $13 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $44 million with investment-grade counterparties, $25 million with commodity exchange brokers, $47 million with independent system operators and $2 million with non-rated counterparties. CECONY’s net credit exposure consisted of $3 million with investment-grade counterparties and $10 million with commodity exchange brokers.

Economic Hedges

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

The fair values of the Companies’ commodity derivatives at September 30, 2012 were:

(Millions of Dollars)	Fair Value of Commodity Derivatives (a) Balance Sheet Location	Con Edison			CECONY
Derivative Assets
Current	Other current assets		$   91			$ 30
Long-term	Other deferred charges and non-current assets		19			10
Total derivative assets			$ 110			$ 40
Impact of netting			(59	)		(13	)
Net derivative assets			$   51			$ 27

Derivative Liabilities
Current	Fair value of derivative liabilities	$ 149		$ 60
Long-term	Fair value of derivative liabilities	53		28
Total derivative liabilities		$ 202		$ 88
Impact of netting		(118	)	(46	)
Net derivative liabilities		$   84		$ 42

(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
Derivative Assets
Current	Other current assets		$ 139			$  16
Long-term	Other deferred charges and non-current assets		26			14
Total derivative assets			$ 165			$  30
Impact of netting			(95	)		(6	)
Net derivative assets			$   70			$  24
Derivative Liabilities
Current	Fair value of derivative liabilities		$ 331			$127
Long-term	Fair value of derivative liabilities		83			48
Total derivative liabilities			$ 414			$175
Impact of netting			(205	)		(53	)
Net derivative liabilities			$ 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 tables present the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2012:

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Three Months Ended September 30, 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		$   5			$   5
Long-term	Deferred derivative gains		1			1
Total deferred gains/(losses)			$   6			$   6
Current	Deferred derivative losses		$ 51			$ 42
Current	Recoverable energy costs		(60	)		(52	)
Long-term	Deferred derivative losses		22			20
Total deferred gains/(losses)			$ 13			$ 10
Net deferred gains/(losses)			$ 19			$ 16
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$   9	(b)		$  —
	Gas purchased for resale		—			—
	Non-utility revenue		1	(b)		—
Total pre-tax gain/(loss) recognized in income			$ 10			$  —

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

(b) For the three months ended September 30, 2012, Con Edison recorded in purchased power expense an unrealized pre-tax gain/(loss) of $30 million.

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 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		$     5			$     5
Long-term	Deferred derivative gains		1			1
Total deferred gains/(losses)			$     6			$     6
Current	Deferred derivative losses		$   89			$   78
Current	Recoverable energy costs		(187	)		(164	)
Long-term	Deferred derivative losses		13			19
Total deferred gains/(losses)			$  (85	)		$  (67	)
Net deferred gains/(losses)			$  (79	)		$  (61	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$  (49	)(b)		$    —
	Gas purchased for resale		(2	)		—
	Non-utility revenue		(11	)(b)		—
Total pre-tax gain/(loss) recognized in income			$  (62	)		$    —

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

(b) For the nine months ended September 30, 2012, Con Edison recorded in non-utility revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(13) million and $75 million, respectively.

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

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

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

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

Realized and Unrealized Gains/(Losses) on Commodity Derivatives (a) Deferred or Recognized in Income for the Nine Months Ended September 30, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains		$    —			$    —
Long-term	Regulatory liabilities		3			3
Total deferred gains/(losses)			$     3			$     3
Current	Deferred derivative losses		$   80			$   60
Current	Recoverable energy costs		(177	)		(134	)
Long-term	Regulatory assets		38			27
Total deferred gains/(losses)			$  (59	)		$  (47	)
Net deferred gains/(losses)			$  (56	)		$  (44	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense		$   81	(b)		$    —
	Gas purchased for resale		17			—
	Non-utility revenue		22	(b)		—
Total pre-tax gain/(loss) recognized in income			$ 120			$    —

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

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

As of September 30, 2012, Con Edison had 1,289 contracts, including 628 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)		MW-Months (b)		Number of Contracts (a)		dths (b)		Total Number of Contracts (a)
Con Edison		576		12,807,613		78		10,019		635		86,541,700		1,289
CECONY		113		3,271,000		—		—		515		81,080,000		628

(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 the clearing and settlement of derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statement of cash flows. Most derivative instrument contracts contain provisions that may require the Companies to provide collateral on derivative instruments in net liability positions. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the Companies’ credit ratings.

The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position and collateral posted at September 30, 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		$62			$41
Collateral posted		$14			$  9
Additional collateral (b) (downgrade one level from current ratings (c))		$ —			$ —
Additional collateral (b) (downgrade to below investment grade from current ratings (c))		$85	(d)		$45	(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 September 30, 2012, would have amounted to an estimated $25 million for Con Edison. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

(b) 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 September 30, 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 $27 million.

Interest Rate Swap

O&R has an interest rate swap pursuant to which it pays a fixed-rate of 6.09 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at September 30, 2012 was an unrealized loss of $6 million, which has been included in Con Edison’s consolidated balance sheet as a noncurrent liability/fair value of derivative liabilities and a regulatory asset. The increase in the fair value of the swap for the three and nine months ended September 30, 2012 was $1 million and $2 million, respectively. 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

9 Months Ended

Sep. 30, 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 and nine months ended September 30, 2012 and 2011 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost		$   6			$   7			$   5			$   5
Interest cost on accumulated other postretirement benefit obligation		18			20			16			18
Expected return on plan assets		(21	)		(22	)		(19	)		(21	)
Amortization of net actuarial loss		24			22			22			20
Amortization of prior service cost		(5	)		(3	)		(4	)		(3	)
Amortization of transition obligation		—			1			—			1
NET PERIODIC POSTRETIREMENT BENEFIT COST		$ 22			$ 25			$ 20			$ 20
Cost capitalized		(8	)		(9	)		(7	)		(7	)
Reconciliation to rate level		3			3			3			3
Cost charged to operating expenses		$ 17			$ 19			$ 16			$ 16

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost		$ 20			$ 19			$ 15			$ 15
Interest cost on accumulated other postretirement benefit obligation		55			62			48			54
Expected return on plan assets		(64	)		(66	)		(56	)		(59	)
Amortization of net actuarial loss		73			66			65			60
Amortization of prior service cost		(16	)		(7	)		(13	)		(9	)
Amortization of transition obligation		1			3			1			3
NET PERIODIC POSTRETIREMENT BENEFIT COST		$ 69			$ 77			$ 60			$ 64
Cost capitalized		(24	)		(27	)		(20	)		(22	)
Reconciliation to rate level		15			12			12			10
Cost charged to operating expenses		$ 60			$ 62			$ 52			$ 52

Expected Contributions

Con Edison expects to make a contribution of $83 million, including $71 million for CECONY, to the other postretirement benefit plans in 2012. During the first nine months of 2012, Con Edison contributed $34 million to the other postretirement benefit plans (of which $28 million was contributed by CECONY).

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 and nine months ended September 30, 2012 and 2011 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost		$   6			$   7			$   5			$   5
Interest cost on accumulated other postretirement benefit obligation		18			20			16			18
Expected return on plan assets		(21	)		(22	)		(19	)		(21	)
Amortization of net actuarial loss		24			22			22			20
Amortization of prior service cost		(5	)		(3	)		(4	)		(3	)
Amortization of transition obligation		—			1			—			1
NET PERIODIC POSTRETIREMENT BENEFIT COST		$ 22			$ 25			$ 20			$ 20
Cost capitalized		(8	)		(9	)		(7	)		(7	)
Reconciliation to rate level		3			3			3			3
Cost charged to operating expenses		$ 17			$ 19			$ 16			$ 16

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost		$ 20			$ 19			$ 15			$ 15
Interest cost on accumulated other postretirement benefit obligation		55			62			48			54
Expected return on plan assets		(64	)		(66	)		(56	)		(59	)
Amortization of net actuarial loss		73			66			65			60
Amortization of prior service cost		(16	)		(7	)		(13	)		(9	)
Amortization of transition obligation		1			3			1			3
NET PERIODIC POSTRETIREMENT BENEFIT COST		$ 69			$ 77			$ 60			$ 64
Cost capitalized		(24	)		(27	)		(20	)		(22	)
Reconciliation to rate level		15			12			12			10
Cost charged to operating expenses		$ 60			$ 62			$ 52			$ 52

Expected Contributions

Con Edison expects to make a contribution of $83 million, including $71 million for CECONY, to the other postretirement benefit plans in 2012. During the first nine months of 2012, Con Edison contributed $34 million to the other postretirement benefit plans (of which $28 million was contributed by CECONY).

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Fair Value Measurements - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative assets	$ 2		$ 11
Gains (loss) on Level 3 energy derivative liabilities		10		35
Loss on Level 3 energy derivative assets for purchased power costs	2		42
Gain (loss) on Level 3 energy derivative liabilities for purchased power costs		12		6
Fair value, assets measured on recurring basis, change in unrealized gain (loss) included in other income	2	10	11	35
Fair value, assets measured on recurring basis, change in unrealized gain (loss) included in purchased power costs	16	5
Change in fair value [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Loss on Level 3 energy derivative assets for purchased power costs			40
Gain (loss) on Level 3 energy derivative liabilities for purchased power costs				$ 31

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Short-Term Borrowing

9 Months Ended

Sep. 30, 2012

Short-Term Borrowing

Note D — Short-Term Borrowing

At September 30, 2012, Con Edison had $340 million of commercial paper outstanding, $332 million of which was outstanding under CECONY’s program. The weighted average interest rate was 0.3 percent for each of Con Edison and CECONY. The Companies have not borrowed under their October 2011 credit agreement. Con Edison had $207 million of letters of credit outstanding under the credit agreement (including $192 million for CECONY).

CECONY [Member]

Short-Term Borrowing

Note D — Short-Term Borrowing

At September 30, 2012, Con Edison had $340 million of commercial paper outstanding, $332 million of which was outstanding under CECONY’s program. The weighted average interest rate was 0.3 percent for each of Con Edison and CECONY. The Companies have not borrowed under their October 2011 credit agreement. Con Edison had $207 million of letters of credit outstanding under the credit agreement (including $192 million for CECONY).

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Pension Benefits

9 Months Ended

Sep. 30, 2012

Pension Benefits

Note E — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic benefit costs for the three and nine months ended September 30, 2012 and 2011 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses		$   59			$   48			$   55			$   45
Interest cost on projected benefit obligation		137			140			128			131
Expected return on plan assets		(176	)		(184	)		(168	)		(174	)
Amortization of net actuarial loss		177			133			168			126
Amortization of prior service costs		2			2			2			—
NET PERIODIC BENEFIT COST		$ 199			$ 139			$ 185			$ 128
Cost capitalized		(64	)		(45	)		(60	)		(42	)
Reconciliation to rate level		—			(11	)		(1	)		(11	)
Cost charged to operating expenses		$ 135			$   83			$ 124			$   75

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses		$ 177			$ 142			$ 165			$ 133
Interest cost on projected benefit obligation		410			420			385			393
Expected return on plan assets		(528	)		(550	)		(503	)		(524	)
Amortization of net actuarial loss		531			397			503			376
Amortization of prior service costs		6			6			4			4
NET PERIODIC BENEFIT COST		$ 596			$ 415			$ 554			$ 382
Amortization of regulatory asset		1			1			1			1
TOTAL PERIODIC BENEFIT COST		$ 597			$ 416			$ 555			$ 383
Cost capitalized		(200	)		(141	)		(186	)		(131	)
Reconciliation to rate level		(37	)		(68	)		(36	)		(70	)
Cost charged to operating expenses		$ 360			$ 207			$ 333			$ 182

Expected Contributions

The Companies made contributions to the pension plan during 2012 of $775 million (of which $721 million was contributed by CECONY). The Companies’ policy is to fund their pension plan’s accounting cost to the extent tax deductible. During the first nine months of 2012, CECONY also funded $12 million for the non-qualified supplemental plan.

CECONY [Member]

Pension Benefits

Note E — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic benefit costs for the three and nine months ended September 30, 2012 and 2011 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses		$   59			$   48			$   55			$   45
Interest cost on projected benefit obligation		137			140			128			131
Expected return on plan assets		(176	)		(184	)		(168	)		(174	)
Amortization of net actuarial loss		177			133			168			126
Amortization of prior service costs		2			2			2			—
NET PERIODIC BENEFIT COST		$ 199			$ 139			$ 185			$ 128
Cost capitalized		(64	)		(45	)		(60	)		(42	)
Reconciliation to rate level		—			(11	)		(1	)		(11	)
Cost charged to operating expenses		$ 135			$   83			$ 124			$   75

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses		$ 177			$ 142			$ 165			$ 133
Interest cost on projected benefit obligation		410			420			385			393
Expected return on plan assets		(528	)		(550	)		(503	)		(524	)
Amortization of net actuarial loss		531			397			503			376
Amortization of prior service costs		6			6			4			4
NET PERIODIC BENEFIT COST		$ 596			$ 415			$ 554			$ 382
Amortization of regulatory asset		1			1			1			1
TOTAL PERIODIC BENEFIT COST		$ 597			$ 416			$ 555			$ 383
Cost capitalized		(200	)		(141	)		(186	)		(131	)
Reconciliation to rate level		(37	)		(68	)		(36	)		(70	)
Cost charged to operating expenses		$ 360			$ 207			$ 333			$ 182

Expected Contributions

The Companies made contributions to the pension plan during 2012 of $775 million (of which $721 million was contributed by CECONY). The Companies’ policy is to fund their pension plan’s accounting cost to the extent tax deductible. During the first nine months of 2012, CECONY also funded $12 million for the non-qualified supplemental plan.

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Environmental Matters

9 Months Ended

Sep. 30, 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 September 30, 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		$352		$307
Other Superfund Sites		71		67		71		66
Total		$537		$489		$423		$373
Regulatory assets		$722		$681		$607		$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 and nine months ended September 30, 2012 and 2011, were as follows:

	For the Three Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred		$3		$9		$1		$9
Insurance recoveries received		—		—		—		—

	For the Nine Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred		$18		$24		$15		$22
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 September 30, 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		$94		$98		$89		$93
Regulatory assets – workers’ compensation		$19		$23		$19		$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 September 30, 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		$352		$307
Other Superfund Sites		71		67		71		66
Total		$537		$489		$423		$373
Regulatory assets		$722		$681		$607		$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 and nine months ended September 30, 2012 and 2011, were as follows:

	For the Three Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred		$3		$9		$1		$9
Insurance recoveries received		—		—		—		—

	For the Nine Months Ended September 30,
	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred		$18		$24		$15		$22
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 September 30, 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		$94		$98		$89		$93
Regulatory assets – workers’ compensation		$19		$23		$19		$23

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Regulatory Matters - Additional Information (Detail) (USD $)	1 Months Ended	9 Months Ended
	Feb. 28, 2009	Sep. 30, 2012	Mar. 31, 2012	Oct. 01, 2010
Schedule Of Regulatory Assets And Liabilities [Line Items]
Surcharge collected from customers			$ 134,000,000
Potential operational penalties		3,000,000
Revenue from electric	249,000,000
Revenue from gas	32,000,000
Revenue from steam service	6,000,000
Potential refund from customers		1,031,000,000
Provisional assessment				21,000,000
Regulatory liability		15,000,000
July 2012 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Electric base rate increase		19.4
Surcharge payment		15,200,000
July 2013 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Electric base rate increase		8.8
Surcharge payment		15,200,000
July 2014 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Electric base rate increase		15.2
Surcharge payment		15,200,000
June 30, 2013 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Weighted average cost of capital		7.61%
Return on common equity		9.40%
Cost of long term debt		6.07%
Common equity ratio		48.00%
Average base rate		671,000,000
Percentage of revenue allocated to customers		50.00%
Common equity basis points		80
Average net utility plant rates		678,000,000
June 30, 2014 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Weighted average cost of capital		7.65%
Return on common equity		9.50%
Cost of long term debt		6.07%
Common equity ratio		48.00%
Average base rate		708,000,000
Percentage of revenue allocated to customers		75.00%
Common equity basis points		180
Average net utility plant rates		704,000,000
June 30, 2015 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Weighted average cost of capital		7.48%
Return on common equity		9.60%
Cost of long term debt		5.64%
Common equity ratio		48.00%
Average base rate		759,000,000
Percentage of revenue allocated to customers		90.00%
Common equity basis points		280
Average net utility plant rates		$ 753,000,000
Maximum [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Common equity ratio		50.00%

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Derivative Instruments And Hedging Activities - Energy Price Hedging Fair Values (Detail) (USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Sep. 30, 2011
Con Edison [Member]
Derivatives And Hedging Activities [Line Items]
Fair value of net derivative assets/(liabilities) - gross	$ (92)	$ (249)
Impact of netting of cash collateral	59	110
Fair value of net derivative assets/(liabilities) - net	(33)	(139)
CECONY [Member]
Derivatives And Hedging Activities [Line Items]
Fair value of net derivative assets/(liabilities) - gross	(48)	(144)
Impact of netting of cash collateral	33	46
Fair value of net derivative assets/(liabilities) - net	$ (15)	$ (98)

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Hurricane Sandy

9 Months Ended

Sep. 30, 2012

Hurricane Sandy

Note L — Hurricane Sandy

In late October 2012, Hurricane Sandy caused extensive damage to the Utilities’ electric distribution system and interrupted service to approximately 950,000 CECONY customers and approximately 250,000 O&R customers. Hurricane Sandy also damaged CECONY’s steam system and interrupted service to many of its steam customers. To restore service to their customers and repair their energy systems, the Utilities are incurring substantial operating costs and making substantial capital expenditures, the amount of which the Utilities are unable to estimate at this time. The Utilities' rate plans provide for operating costs and capital expenditures under different provisions. The Utilities expect that most of their operating expenses attributable to Hurricane Sandy will be deferred for recovery as a regulatory asset under their electric rate plans. The Utilities’ capital expenditures, up to specified levels, are reflected in rates under their rate plans. In addition, CECONY's rate plans, provide that it may request in its next base rate filings to recover additional capital expenditures (provided the company can justify the need for and reasonableness of, and its inability to reasonably avoid, such additional capital expenditures). Under its New York electric rate plan and subject to certain limitations, O&R defers as a regulatory asset the revenue requirement impact of the amount by which actual average net utility plant is different than the average net utility plant reflected in rates. Under the New York rate plans, the Utilities also may petition the NYSPSC for authorization to defer extraordinary expenditures not otherwise addressed in their rate plans. The Utilities’ New York electric rate plans include provisions for revenue decoupling, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved. The provisions of the Utilities' New York electric plans that impose penalties for operating performance provide for exceptions for major storms and catastrophic events beyond the control of the companies, including natural disasters such as hurricanes and floods. The Utilities expect the NYSPSC to investigate the preparation and performance of New York utilities in connection with Hurricane Sandy.

CECONY [Member]

Hurricane Sandy

Note L — Hurricane Sandy

In late October 2012, Hurricane Sandy caused extensive damage to the Utilities’ electric distribution system and interrupted service to approximately 950,000 CECONY customers and approximately 250,000 O&R customers. Hurricane Sandy also damaged CECONY’s steam system and interrupted service to many of its steam customers. To restore service to their customers and repair their energy systems, the Utilities are incurring substantial operating costs and making substantial capital expenditures, the amount of which the Utilities are unable to estimate at this time. The Utilities' rate plans provide for operating costs and capital expenditures under different provisions. The Utilities expect that most of their operating expenses attributable to Hurricane Sandy will be deferred for recovery as a regulatory asset under their electric rate plans. The Utilities’ capital expenditures, up to specified levels, are reflected in rates under their rate plans. In addition, CECONY's rate plans, provide that it may request in its next base rate filings to recover additional capital expenditures (provided the company can justify the need for and reasonableness of, and its inability to reasonably avoid, such additional capital expenditures). Under its New York electric rate plan and subject to certain limitations, O&R defers as a regulatory asset the revenue requirement impact of the amount by which actual average net utility plant is different than the average net utility plant reflected in rates. Under the New York rate plans, the Utilities also may petition the NYSPSC for authorization to defer extraordinary expenditures not otherwise addressed in their rate plans. The Utilities’ New York electric rate plans include provisions for revenue decoupling, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved. The provisions of the Utilities' New York electric plans that impose penalties for operating performance provide for exceptions for major storms and catastrophic events beyond the control of the companies, including natural disasters such as hurricanes and floods. The Utilities expect the NYSPSC to investigate the preparation and performance of New York utilities in connection with Hurricane Sandy.

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Pension Benefits (Tables)

9 Months Ended

Sep. 30, 2012

Companies' Net Periodic Benefit Costs

The components of the Companies’ net periodic benefit costs for the three and nine months ended September 30, 2012 and 2011 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses		$   59			$   48			$   55			$   45
Interest cost on projected benefit obligation		137			140			128			131
Expected return on plan assets		(176	)		(184	)		(168	)		(174	)
Amortization of net actuarial loss		177			133			168			126
Amortization of prior service costs		2			2			2			—
NET PERIODIC BENEFIT COST		$ 199			$ 139			$ 185			$ 128
Cost capitalized		(64	)		(45	)		(60	)		(42	)
Reconciliation to rate level		—			(11	)		(1	)		(11	)
Cost charged to operating expenses		$ 135			$   83			$ 124			$   75

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost – including administrative expenses		$ 177			$ 142			$ 165			$ 133
Interest cost on projected benefit obligation		410			420			385			393
Expected return on plan assets		(528	)		(550	)		(503	)		(524	)
Amortization of net actuarial loss		531			397			503			376
Amortization of prior service costs		6			6			4			4
NET PERIODIC BENEFIT COST		$ 596			$ 415			$ 554			$ 382
Amortization of regulatory asset		1			1			1			1
TOTAL PERIODIC BENEFIT COST		$ 597			$ 416			$ 555			$ 383
Cost capitalized		(200	)		(141	)		(186	)		(131	)
Reconciliation to rate level		(37	)		(68	)		(36	)		(70	)
Cost charged to operating expenses		$ 360			$ 207			$ 333			$ 182

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Financial Information By Business Segment - Financial Data for the Business Segments (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2012		Sep. 30, 2011		Sep. 30, 2012		Sep. 30, 2011
Segment Reporting Information [Line Items]
Depreciation and amortization					$ 709		$ 659
Operating income	851		756		1,886		1,781
CECONY [Member]
Segment Reporting Information [Line Items]
Operating revenues	2,868		2,917		7,738		8,042
Depreciation and amortization	225		209		664		618
Operating income	754		702		1,678		1,619
O&R [Member]
Segment Reporting Information [Line Items]
Operating revenues	226		241		601		660
Depreciation and amortization	13		12		39		36
Operating income	44		38		100		91
Consolidated Edison Inc [Member]
Segment Reporting Information [Line Items]
Operating revenues	3,438		3,629		9,287		9,972
Depreciation and amortization	240		222		709		659
Operating income	851		756		1,886		1,781
CECONY - Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	2,611		2,644		6,307		6,378
Inter-segment revenues	4		3		11		9
Depreciation and amortization	179		166		527		489
Operating income	812		758		1,383		1,326
CECONY - Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	189		197		1,017		1,156
Inter-segment revenues	1		1		4		4
Depreciation and amortization	31		28		89		82
Operating income	(21)		(23)		255		212
CECONY - Steam [Member]
Segment Reporting Information [Line Items]
Operating revenues	68		76		414		508
Inter-segment revenues	20		20		58		59
Depreciation and amortization	15		15		48		47
Operating income	(37)		(33)		40		81
Consolidation Adjustments [Member]
Segment Reporting Information [Line Items]
Inter-segment revenues	(25)		(24)		(73)		(72)
O&R - Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	199		217		457		507
Depreciation and amortization	10		9		28		26
Operating income	50		44		74		69
O&R - Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	27		24		144		153
Depreciation and amortization	3		3		11		10
Operating income	(6)		(6)		26		22
Competitive Energy Businesses [Member]
Segment Reporting Information [Line Items]
Operating revenues	344		472		954		1,286
Inter-segment revenues	2		3		6		9
Depreciation and amortization	2		1		6		5
Operating income	53		16		111		75
Other Revenues And Eliminations In Segment Information [Member]
Segment Reporting Information [Line Items]
Operating revenues			(1)	[1]	(6)	[1]	(16)	[1]
Inter-segment revenues	(2)	[1]	(3)	[1]	(6)	[1]	(9)	[1]
Operating income					$ (3)	[1]	$ (4)	[1]

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

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Other Postretirement Benefits - Net Periodic Postretirement Benefit Costs (Detail) (Other Postretirement Benefit Plans, Defined Benefit [Member], USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Con Edison [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Service cost	$ 6	$ 7	$ 20	$ 19
Interest cost on accumulated other postretirement benefit obligation	18	20	55	62
Expected return on plan assets	(21)	(22)	(64)	(66)
Amortization of net actuarial loss	24	22	73	66
Amortization of prior service cost	(5)	(3)	(16)	(7)
Amortization of transition obligation		1	1	3
NET PERIODIC BENEFIT COST	22	25	69	77
Cost capitalized	(8)	(9)	(24)	(27)
Reconciliation to rate level	3	3	15	12
Cost charged to operating expenses	17	19	60	62
CECONY [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Service cost	5	5	15	15
Interest cost on accumulated other postretirement benefit obligation	16	18	48	54
Expected return on plan assets	(19)	(21)	(56)	(59)
Amortization of net actuarial loss	22	20	65	60
Amortization of prior service cost	(4)	(3)	(13)	(9)
Amortization of transition obligation		1	1	3
NET PERIODIC BENEFIT COST	20	20	60	64
Cost capitalized	(7)	(7)	(20)	(22)
Reconciliation to rate level	3	3	12	10
Cost charged to operating expenses	$ 16	$ 16	$ 52	$ 52

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CONSOLIDATED STATEMENT OF CASH FLOWS (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
OPERATING ACTIVITIES
Net Income	$ 934	$ 869
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	709	659
Deferred income taxes	344	368
Rate case amortization and accruals	32	39
Common equity component of allowance for funds used during construction	(3)	(8)
Net derivative gains	(61)	(25)
Other non-cash items (net)	(53)	6
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	(196)	(4)
Materials and supplies, including fuel oil and gas in storage	1	(27)
Other receivables and other current assets	54	70
Prepayments	(288)	(128)
Accounts payable	18	(50)
Pensions and retiree benefits obligations	713	578
Pensions and retiree benefits contributions	(821)	(579)
Accrued taxes	(80)	76
Accrued interest	46	57
Superfund and environmental remediation costs (net)	7
Deferred charges, noncurrent assets and other regulatory assets	183	92
Deferred credits and other regulatory liabilities	83	158
Other liabilities	16	10
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,638	2,161
INVESTING ACTIVITIES
Utility construction expenditures	(1,450)	(1,404)
Cost of removal less salvage	(118)	(123)
Non-utility construction expenditures	(68)	(57)
Acquisition of Alpaugh solar energy projects	(286)
Proceeds from grants related to renewable energy investments	27	4
Net investment in Pilesgrove solar project and other	28	(31)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,867)	(1,611)
FINANCING ACTIVITIES
Net proceeds from short-term debt	340
Preferred stock redemption	(239)
Retirement of long-term debt	(304)	(3)
Issuance of long-term debt	400
Issuance of common shares for stock plans, net of repurchases	(16)	41
Debt issuance costs	(4)
Common stock dividends	(524)	(519)
Preferred stock dividends	(3)	(9)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(350)	(490)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(579)	60
BALANCE AT BEGINNING OF PERIOD	648	338
BALANCE AT END OF PERIOD	69	398
Cash paid/(refunded) during the period for:
Interest	379	371
Income taxes	46	(132)
CECONY [Member]
OPERATING ACTIVITIES
Net Income	827	788
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	664	618
Deferred income taxes	220	309
Rate case amortization and accruals	32	38
Common equity component of allowance for funds used during construction	(2)	(6)
Other non-cash items (net)	84	60
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	(197)	3
Materials and supplies, including fuel oil and gas in storage	12	2
Other receivables and other current assets	(41)	243
Prepayments	(308)	(303)
Accounts payable	50	(45)
Pensions and retiree benefits obligations	639	527
Pensions and retiree benefits contributions	(761)	(532)
Accrued taxes	40	(7)
Accrued interest	46	46
Superfund and environmental remediation costs (net)	7
Deferred charges, noncurrent assets and other regulatory assets	84	33
Deferred credits and other regulatory liabilities	88	167
Other liabilities	(21)	19
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,463	1,960
INVESTING ACTIVITIES
Utility construction expenditures	(1,368)	(1,332)
Cost of removal less salvage	(115)	(118)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,483)	(1,450)
FINANCING ACTIVITIES
Net proceeds from short-term debt	332
Preferred stock redemption	(239)
Retirement of long-term debt	(300)
Issuance of long-term debt	400
Debt issuance costs	(4)
Dividend to parent	(512)	(509)
Preferred stock dividends	(3)	(9)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(326)	(518)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(346)	(8)
BALANCE AT BEGINNING OF PERIOD	372	78
BALANCE AT END OF PERIOD	26	70
Cash paid/(refunded) during the period for:
Interest	344	336
Income taxes	$ 50	$ (103)

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Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2012

Summary of Significant Accounting Policies

Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

For the three and nine months ended September 30, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2012		2011
Net income for common stock		$   440		$   383		$   931		$   860
Weighted average common shares outstanding – basic		292.9		292.9		292.9		292.5
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.7		1.7		1.7
Adjusted weighted average common shares outstanding – diluted		294.6		294.6		294.6		294.2
Net income for common stock per common share – basic		$  1.50		$  1.31		$  3.18		$  2.94
Net income for common stock per common share – diluted		$  1.49		$  1.30		$  3.16		$  2.92

CECONY [Member]

Summary of Significant Accounting Policies

Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

For the three and nine months ended September 30, 2012 and 2011, basic and diluted EPS for Con Edison are calculated as follows:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2012		2011
Net income for common stock		$   440		$   383		$   931		$   860
Weighted average common shares outstanding – basic		292.9		292.9		292.9		292.5
Add: Incremental shares attributable to effect of potentially dilutive securities		1.7		1.7		1.7		1.7
Adjusted weighted average common shares outstanding – diluted		294.6		294.6		294.6		294.2
Net income for common stock per common share – basic		$  1.50		$  1.31		$  3.18		$  2.94
Net income for common stock per common share – diluted		$  1.49		$  1.30		$  3.16		$  2.92

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Fair Value Measurements - Schedule of Commodity Derivatives (Detail) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012
Con Edison [Member] | Electricity Swaps [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
Con Edison [Member] | Electricity Wholesale Contract [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
Con Edison [Member] | Standard Offer Capacity Agreements [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
Con Edison [Member] | Transmission Congestion Contracts Or Financial Transmission Rights [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
Con Edison [Member] | Minimum [Member] | Forward prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	22	[1]
Con Edison [Member] | Minimum [Member] | Auction prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	29	[2]
Con Edison [Member] | Minimum [Member] | New Jersey solar [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	85	[2]
Con Edison [Member] | Minimum [Member] | Forward capacity prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	166	[1]
Con Edison [Member] | Minimum [Member] | Forward price escalator [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	0.00%	[1]
Con Edison [Member] | Minimum [Member] | Present value factor [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	1.66%	[1]
Con Edison [Member] | Minimum [Member] | Discount to adjust auction prices for inter-zonal forward price curves [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	17.50%	[2]
Con Edison [Member] | Minimum [Member] | Discount to adjust auction prices for historical monthly realized settlements [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	(3.00%)	[2]
Con Edison [Member] | Minimum [Member] | Historical line loss factor [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	8.00%	[1]
Con Edison [Member] | Maximum [Member] | Forward prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	64	[1]
Con Edison [Member] | Maximum [Member] | Auction prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	52	[2]
Con Edison [Member] | Maximum [Member] | Forward price escalator [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	(3.00%)	[1]
Con Edison [Member] | Maximum [Member] | Discount to adjust auction prices for inter-zonal forward price curves [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	(38.00%)	[2]
Con Edison [Member] | Maximum [Member] | Discount to adjust auction prices for historical monthly realized settlements [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	26.50%	[2]
Con Edison [Member] | Level 3 [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	(3)
Con Edison [Member] | Level 3 [Member] | Electricity Swaps [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	(9)
Con Edison [Member] | Level 3 [Member] | Electricity Wholesale Contract [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	4
Con Edison [Member] | Level 3 [Member] | Standard Offer Capacity Agreements [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	(12)
Con Edison [Member] | Level 3 [Member] | Transmission Congestion Contracts Or Financial Transmission Rights [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	14
CECONY [Member] | Transmission Congestion Contracts [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
CECONY [Member] | Minimum [Member] | Discount to adjust auction prices for inter-zonal forward price curves [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	17.50%	[2]
CECONY [Member] | Minimum [Member] | Discount to adjust auction prices for historical monthly realized settlements [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	(3.00%)	[2]
CECONY [Member] | Maximum [Member] | Discount to adjust auction prices for inter-zonal forward price curves [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	38.00%	[2]
CECONY [Member] | Maximum [Member] | Discount to adjust auction prices for historical monthly realized settlements [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	26.50%	[2]
CECONY [Member] | Level 3 [Member] | Transmission Congestion Contracts [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	12

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

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

XML

Other Postretirement Benefits (Tables)

9 Months Ended

Sep. 30, 2012

Net Periodic Postretirement Benefit Costs

The components of the Companies’ net periodic postretirement benefit costs for the three and nine months ended September 30, 2012 and 2011 were as follows:

	For the Three Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost		$   6			$   7			$   5			$   5
Interest cost on accumulated other postretirement benefit obligation		18			20			16			18
Expected return on plan assets		(21	)		(22	)		(19	)		(21	)
Amortization of net actuarial loss		24			22			22			20
Amortization of prior service cost		(5	)		(3	)		(4	)		(3	)
Amortization of transition obligation		—			1			—			1
NET PERIODIC POSTRETIREMENT BENEFIT COST		$ 22			$ 25			$ 20			$ 20
Cost capitalized		(8	)		(9	)		(7	)		(7	)
Reconciliation to rate level		3			3			3			3
Cost charged to operating expenses		$ 17			$ 19			$ 16			$ 16

	For the Nine Months Ended September 30,
	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Service cost		$ 20			$ 19			$ 15			$ 15
Interest cost on accumulated other postretirement benefit obligation		55			62			48			54
Expected return on plan assets		(64	)		(66	)		(56	)		(59	)
Amortization of net actuarial loss		73			66			65			60
Amortization of prior service cost		(16	)		(7	)		(13	)		(9	)
Amortization of transition obligation		1			3			1			3
NET PERIODIC POSTRETIREMENT BENEFIT COST		$ 69			$ 77			$ 60			$ 64
Cost capitalized		(24	)		(27	)		(20	)		(22	)
Reconciliation to rate level		15			12			12			10
Cost charged to operating expenses		$ 60			$ 62			$ 52			$ 52

XML

Short-Term Borrowing - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012
Short-term Debt [Line Items]
Weighted average interest rate	0.30%
Consolidated Edison Inc [Member]
Short-term Debt [Line Items]
Commercial paper outstanding	340
Letters of credit outstanding under the Credit Agreement	207
CECONY [Member]
Short-term Debt [Line Items]
Commercial paper outstanding	332
Letters of credit outstanding under the Credit Agreement	192

XML

Fair Value Measurements

9 Months Ended

Sep. 30, 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 September 30, 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			$  2		$  48			$  16			$   47			$ 12			$  (46	)		$  (3	)		$   51			$  27
Transfer in (5) (6)		—			—		24			—			—			—			—			—			24			—
Transfer out (5) (6)		—			—		—			—			(24	)		—			—			—			(24	)		—
Commodity Total		$    2			$  2		$  72			$  16			$   23			$ 12			$  (46	)		$  (3	)		$ 51			$  27
Other assets		103			96		—			1			105			95			—			—			208			192
Transfer in (5) (6)		—			—		105			95			—			—			—			—			105			95
Transfer out (5) (6)		—			—		—			—			(105	)		(95	)		—			—			(105	)		(95	)
Other assets (3)		$103			$96		$105			$  96			$    —			$  —			$    —			$  —			$ 208			$192
Total		$105			$98		$177			$112			$   23			$ 12			$  (46	)		$  (3	)		$ 259			$219
Derivative liabilities:
Commodity		$    4			$  1		$114			$  68			$   71			$   9			$(105	)		$(36	)		$   84			$  42
Transfer in (5) (6)		7			7		50			12			3			3			—			—			60			22
Transfer out (5) (6)		(2	)		—		(10	)		(10	)		(48	)		(12	)		—			—			(60	)		(22	)
Commodity Total (1)		$9			$  8		$154			$  70			$   26			$  —			$(105	)		$(36	)		$   84			$  42
Interest rate contract		—			—		(2	)		—			8			—			—			—			6			—
Transfer in (5) (6)		—			—		8			—			—			—			—			—			8			—
Transfer out (5) (6)		—			—		—			—			(8	)		—			—			—			(8	)		—
Interest rate contract (2)		$   —			$ —		$    6			$ —			$    —			$  —			$    —			$  —			$     6			$   —
Total		$    9			$  8		$160			$70			$   26			$  —			$(105	)		$(36	)		$   90			$  42

(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 between Level 3 and Levels 1 and 2 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall. Other assets and interest rate contract were transferred as of March 31, 2012.

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.

	Fair Value of Level 3 at September 30, 2012 (Millions of Dollars)			Valuation Techniques	Unobservable Inputs	Range
Con Edison—Commodity
Electricity Swaps	$	(9	)	Discounted Cash Flow	Forward prices (1)	$22-$64 per MWH
Electricity Wholesale Contract		4		Discounted Cash Flow	Auction prices (2) New Jersey solar renewable energy credit (SREC) (2)	$29-$52 per MWH $85 per SREC
Standard Offer Capacity Agreements		(12	)	Discounted Cash Flow	Forward capacity prices (1) Forward price escalator (1) Present value factor (1)	$166 MW per day 0%-3% 1.66%
Transmission Congestion Contracts / Financial Transmission Rights		14		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (2) Discount to adjust auction prices for historical monthly realized settlements (2) Historical line loss factor (1)	17.5%-38% (3)%-26.5% 8%
Total Con Edison—Commodity	$	(3	)
CECONY—Commodity
Transmission Congestion Contracts	$	12		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (2) Discount to adjust auction prices for historical monthly realized settlements (2)	17.5%-38% (3)%- 26.5%

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

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

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2012 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30, 2012
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 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 September 30, 2012
Con Edison
Derivatives:
Commodity		$(61	)		$(15	)		$19		$7		$—		$—		$25		$22		$  (3	)
CECONY
Derivatives:
Commodity		$(10	)		$  (9	)		$  8		$7		$—		$—		$  5		$11		$ 12

	For the Nine Months Ended September 30, 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 September 30, 2012
Con Edison
Derivatives:
Commodity		$(62)		$(97)		$11		$18		$—		$—		$106		$     21			$ (3)
Interest rate contract		(8)		(1)		—		—		—		—		1		8(2	)		—
Other assets (1)		99		3		3		—		—		—		—		(105	)(2)		—
Total		$  29		$(95)		$14		$18		$—		$—		$107		$   (76)			$ (3)
CECONY
Derivatives:
Commodity		$  (7)		$(25)		$  8		$15		$—		$—		$  12		$    9(2	)		$ 12
Other assets (1)		90		3		2		—		—		—		—		(95	)(2)		—
Total		$  83		$(22)		$10		$15		$—		$—		$  12		$   (86)			$ 12

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

(2) Other assets and interest rate contract were transferred as of March 31, 2012.

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

	For the Three Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity		$ (25	)		$(37	)		$ 9			$8		$—		$—		$14		$24		$    (7	)
Interest rate contract		(10	)		(1	)		1			—		—		—		1		—		(9	)
Other assets (1)		106			(3	)		(3	)		—		—		—		—		—		100
Total		$  71			$(41	)		$ 7			$8		$—		$—		$15		$24		$   84
CECONY
Derivatives:
Commodity		$   —			$  (8	)		$ 1			$8		$—		$—		$  3		$  9		$   13
Other assets (1)		96			(3	)		(2	)		—		—		—		—		—		91
Total		$  96			$(11	)		$(1	)		$8		$—		$—		$  3		$  9		$ 104

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

	For the Nine Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity		$ (88	)		$(59	)		$54			$22		$—		$—		$35			$29		$    (7	)
Interest rate contract		(10	)		(3	)		1			—		—		—		3			—		(9	)
Other assets (1)		101			—			(1	)		—		—		—		—			—		100
Total		$    3			$(62	)		$54			$22		$—		$—		$38			$29		$   84
CECONY
Derivatives:
Commodity		$ (26	)		$(11	)		$22			$18		$—		$—		$ (4	)		$14		$   13
Other assets (1)		92			—			(1	)		—		—		—		—			—		91
Total		$  66			$(11	)		$21			$18		$—		$—		$ (4	)		$14		$ 104

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

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

For the competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($2 million loss and $10 million loss) and purchased power costs ($2 million gain and $12 million loss) on the consolidated income statement for the three months ended September 30, 2012 and 2011, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($11 million loss and $35 million loss), and purchased power costs ($42 million loss and $6 million gain) on the consolidated income statement for the nine months ended September 30, 2012 and 2011, respectively. The change in fair value relating to Level 3 commodity derivative assets held at September 30, 2012 and 2011 is included in non-utility revenues ($2 million loss and $10 million loss), and purchased power costs ($16 million gain and $5 million loss) on the consolidated income statement for the three months ended September 30, 2012 and 2011, respectively. For the nine months ended September 30, 2012 and 2011, the change in fair value relating to Level 3 commodity derivative assets and liabilities included in non-utility revenues ($11 million loss and $35 million loss), and purchased power costs ($40 million gain and $31 million gain) on the consolidated income statement, 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 September 30, 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 September 30, 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			$  2		$  48			$  16			$   47			$ 12			$  (46	)		$  (3	)		$   51			$  27
Transfer in (5) (6)		—			—		24			—			—			—			—			—			24			—
Transfer out (5) (6)		—			—		—			—			(24	)		—			—			—			(24	)		—
Commodity Total		$    2			$  2		$  72			$  16			$   23			$ 12			$  (46	)		$  (3	)		$ 51			$  27
Other assets		103			96		—			1			105			95			—			—			208			192
Transfer in (5) (6)		—			—		105			95			—			—			—			—			105			95
Transfer out (5) (6)		—			—		—			—			(105	)		(95	)		—			—			(105	)		(95	)
Other assets (3)		$103			$96		$105			$  96			$    —			$  —			$    —			$  —			$ 208			$192
Total		$105			$98		$177			$112			$   23			$ 12			$  (46	)		$  (3	)		$ 259			$219
Derivative liabilities:
Commodity		$    4			$  1		$114			$  68			$   71			$   9			$(105	)		$(36	)		$   84			$  42
Transfer in (5) (6)		7			7		50			12			3			3			—			—			60			22
Transfer out (5) (6)		(2	)		—		(10	)		(10	)		(48	)		(12	)		—			—			(60	)		(22	)
Commodity Total (1)		$9			$  8		$154			$  70			$   26			$  —			$(105	)		$(36	)		$   84			$  42
Interest rate contract		—			—		(2	)		—			8			—			—			—			6			—
Transfer in (5) (6)		—			—		8			—			—			—			—			—			8			—
Transfer out (5) (6)		—			—		—			—			(8	)		—			—			—			(8	)		—
Interest rate contract (2)		$   —			$ —		$    6			$ —			$    —			$  —			$    —			$  —			$     6			$   —
Total		$    9			$  8		$160			$70			$   26			$  —			$(105	)		$(36	)		$   90			$  42

(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 between Level 3 and Levels 1 and 2 because of reassessment of the levels in the fair value hierarchy within which certain inputs fall. Other assets and interest rate contract were transferred as of March 31, 2012.

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.

	Fair Value of Level 3 at September 30, 2012 (Millions of Dollars)			Valuation Techniques	Unobservable Inputs	Range
Con Edison—Commodity
Electricity Swaps	$	(9	)	Discounted Cash Flow	Forward prices (1)	$22-$64 per MWH
Electricity Wholesale Contract		4		Discounted Cash Flow	Auction prices (2) New Jersey solar renewable energy credit (SREC) (2)	$29-$52 per MWH $85 per SREC
Standard Offer Capacity Agreements		(12	)	Discounted Cash Flow	Forward capacity prices (1) Forward price escalator (1) Present value factor (1)	$166 MW per day 0%-3% 1.66%
Transmission Congestion Contracts / Financial Transmission Rights		14		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (2) Discount to adjust auction prices for historical monthly realized settlements (2) Historical line loss factor (1)	17.5%-38% (3)%-26.5% 8%
Total Con Edison—Commodity	$	(3	)
CECONY—Commodity
Transmission Congestion Contracts	$	12		Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (2) Discount to adjust auction prices for historical monthly realized settlements (2)	17.5%-38% (3)%- 26.5%

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

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

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and nine months ended September 30, 2012 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30, 2012
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 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 September 30, 2012
Con Edison
Derivatives:
Commodity		$(61	)		$(15	)		$19		$7		$—		$—		$25		$22		$  (3	)
CECONY
Derivatives:
Commodity		$(10	)		$  (9	)		$  8		$7		$—		$—		$  5		$11		$ 12

	For the Nine Months Ended September 30, 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 September 30, 2012
Con Edison
Derivatives:
Commodity		$(62)		$(97)		$11		$18		$—		$—		$106		$     21			$ (3)
Interest rate contract		(8)		(1)		—		—		—		—		1		8(2	)		—
Other assets (1)		99		3		3		—		—		—		—		(105	)(2)		—
Total		$  29		$(95)		$14		$18		$—		$—		$107		$   (76)			$ (3)
CECONY
Derivatives:
Commodity		$  (7)		$(25)		$  8		$15		$—		$—		$  12		$    9(2	)		$ 12
Other assets (1)		90		3		2		—		—		—		—		(95	)(2)		—
Total		$  83		$(22)		$10		$15		$—		$—		$  12		$   (86)			$ 12

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

(2) Other assets and interest rate contract were transferred as of March 31, 2012.

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

	For the Three Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of July 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity		$ (25	)		$(37	)		$ 9			$8		$—		$—		$14		$24		$    (7	)
Interest rate contract		(10	)		(1	)		1			—		—		—		1		—		(9	)
Other assets (1)		106			(3	)		(3	)		—		—		—		—		—		100
Total		$  71			$(41	)		$ 7			$8		$—		$—		$15		$24		$   84
CECONY
Derivatives:
Commodity		$   —			$  (8	)		$ 1			$8		$—		$—		$  3		$  9		$   13
Other assets (1)		96			(3	)		(2	)		—		—		—		—		—		91
Total		$  96			$(11	)		$(1	)		$8		$—		$—		$  3		$  9		$ 104

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

	For the Nine Months Ended September 30, 2011
				Total Gains/(Losses)— Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements			Transfer In/Out of Level 3		Ending Balance as of September 30, 2011
Con Edison
Derivatives:
Commodity		$ (88	)		$(59	)		$54			$22		$—		$—		$35			$29		$    (7	)
Interest rate contract		(10	)		(3	)		1			—		—		—		3			—		(9	)
Other assets (1)		101			—			(1	)		—		—		—		—			—		100
Total		$    3			$(62	)		$54			$22		$—		$—		$38			$29		$   84
CECONY
Derivatives:
Commodity		$ (26	)		$(11	)		$22			$18		$—		$—		$ (4	)		$14		$   13
Other assets (1)		92			—			(1	)		—		—		—		—			—		91
Total		$  66			$(11	)		$21			$18		$—		$—		$ (4	)		$14		$ 104

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

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

For the competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($2 million loss and $10 million loss) and purchased power costs ($2 million gain and $12 million loss) on the consolidated income statement for the three months ended September 30, 2012 and 2011, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($11 million loss and $35 million loss), and purchased power costs ($42 million loss and $6 million gain) on the consolidated income statement for the nine months ended September 30, 2012 and 2011, respectively. The change in fair value relating to Level 3 commodity derivative assets held at September 30, 2012 and 2011 is included in non-utility revenues ($2 million loss and $10 million loss), and purchased power costs ($16 million gain and $5 million loss) on the consolidated income statement for the three months ended September 30, 2012 and 2011, respectively. For the nine months ended September 30, 2012 and 2011, the change in fair value relating to Level 3 commodity derivative assets and liabilities included in non-utility revenues ($11 million loss and $35 million loss), and purchased power costs ($40 million gain and $31 million gain) on the consolidated income statement, 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 September 30, 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.