The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 130

-Paragraph 10, 15

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 03

-Paragraph 19

-Article 5

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 04

-Paragraph 20

-Article 9

Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 95

-Paragraph 28, 29, 30

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 944

-SubTopic 225

-Section S99

-Paragraph 1

-Subparagraph (SX 210.7-04.22)

-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 6

-URI http://asc.fasb.org/extlink&oid=20435746&loc=d3e565-108580

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 230

-SubTopic 10

-Section 45

-Paragraph 28

-URI http://asc.fasb.org/extlink&oid=6943989&loc=d3e3602-108585

Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Glossary Other Comprehensive Income

-URI http://asc.fasb.org/extlink&oid=6519514

Reference 9: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Glossary Net Income

-URI http://asc.fasb.org/extlink&oid=6518256

Reference 10: http://www.xbrl.org/2003/role/presentationRef

-Publisher AICPA

-Name Accounting Research Bulletin (ARB)

-Number 51

-Paragraph 38

-Subparagraph a

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 11: http://www.xbrl.org/2003/role/presentationRef

-Publisher AICPA

-Name Accounting Research Bulletin (ARB)

-Number 51

-Paragraph A7

-Appendix A

Reference 12: http://www.xbrl.org/2003/role/presentationRef

-Publisher AICPA

-Name Accounting Research Bulletin (ARB)

-Number 51

-Paragraph 38

-Subparagraph d

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 13: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 50

-Paragraph 1

-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 14: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 944

-SubTopic 225

-Section S99

-Paragraph 1

-Subparagraph (SX 210.7-04.19)

-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 15: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Emerging Issues Task Force (EITF)

-Number 87-21

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 16: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 225

-SubTopic 10

-Section S99

-Paragraph 2

-Subparagraph (SX 210.5-03.18)

-URI http://asc.fasb.org/extlink&oid=6880815&loc=d3e20235-122688

+ Details

Consolidated Statement of Cash Flows (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
OPERATING ACTIVITIES
Net Income	$ 1,141	$ 1,062	$ 1,003
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	955	884	840
Deferred income taxes	584	491	659
Rate case amortization and accruals	42	49	13
Common equity component of allowance for funds used during construction	(4)	(11)	(15)
Net derivative (gains)/losses	(68)	22	(19)
Other non-cash items (net)	(16)	144	(18)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	(99)	50	(126)
Materials and supplies, including fuel oil and gas in storage	26	(8)	7
Other receivables and other current assets	27	51	207
Prepayments	(14)	196	(210)
Accounts payable	111	(195)	(22)
Pensions and retiree benefits obligations	957	779	633
Pensions and retiree benefits contributions	(870)	(628)	(555)
Superfund and environmental remediation costs (net)	7	(9)	(3)
Accrued taxes	(26)	98	38
Accrued interest	(7)	5	(1)
Deferred charges, noncurrent assets and other regulatory assets	(292)	(139)	(287)
Deferred credits and other regulatory liabilities	92	234	80
Other assets	(31)		(9)
Other liabilities	84	62	166
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,599	3,137	2,381
INVESTING ACTIVITIES
Utility construction expenditures	(1,917)	(1,887)	(1,986)
Cost of removal less salvage	(175)	(167)	(149)
Non-utility construction expenditures	(152)	(80)	(28)
Acquisition of solar energy projects	(337)
Proceeds from grants related to renewable energy investments	30	4
Net investment in Pilesgrove solar project and other	28	(20)
Purchase of additional ownership interest in Honeoye Storage Corporation			(12)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,523)	(2,150)	(2,175)
FINANCING ACTIVITIES
Net proceeds of short-term debt	539
Preferred stock redemption	(239)
Issuance of long-term debt	400		1,095
Retirement of long-term debt	(305)	(4)	(1,011)
Issuance of common shares			306
Issuance of common shares for stock plans, net of repurchases	(9)	31	133
Debt issuance costs	(4)		(11)
Common stock dividends	(709)	(693)	(629)
Preferred stock dividends	(3)	(11)	(11)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(330)	(677)	(128)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(254)	310	78
BALANCE AT BEGINNING OF PERIOD	648	338	260
Balance at End of Period	394	648	338
Interest	571	563	583
Income taxes	46	(236)	(25)
CECONY [Member]
OPERATING ACTIVITIES
Net Income	1,017	989	904
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	894	829	787
Deferred income taxes	365	462	622
Rate case amortization and accruals	42	49	13
Common equity component of allowance for funds used during construction	(2)	(8)	(13)
Other non-cash items (net)	14	96	(12)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	(131)	48	(121)
Materials and supplies, including fuel oil and gas in storage	23	(2)	4
Other receivables and other current assets	(40)	170	11
Prepayments	4	(3)
Accounts payable	102	(132)	(17)
Pensions and retiree benefits obligations	860	678	575
Pensions and retiree benefits contributions	(804)	(576)	(507)
Superfund and environmental remediation costs (net)	9	(9)	(8)
Accrued taxes	94	95	13
Accrued interest		3	(7)
Deferred charges, noncurrent assets and other regulatory assets	(262)	(32)	(294)
Deferred credits and other regulatory liabilities	100	224	70
Other liabilities	61	52	185
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,346	2,933	2,205
INVESTING ACTIVITIES
Utility construction expenditures	(1,788)	(1,785)	(1,853)
Cost of removal less salvage	(170)	(162)	(145)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,958)	(1,947)	(1,998)
FINANCING ACTIVITIES
Net proceeds of short-term debt	421
Preferred stock redemption	(239)
Issuance of long-term debt	400		925
Retirement of long-term debt	(300)		(850)
Debt issuance costs	(4)		(9)
Capital contribution by parent			355
Dividend to parent	(682)	(681)	(670)
Preferred stock dividends	(3)	(11)	(11)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(407)	(692)	(260)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(19)	294	(53)
BALANCE AT BEGINNING OF PERIOD	372	78	131
Balance at End of Period	353	372	78
Interest	513	504	528
Income taxes	$ 62	$ (198)	$ (18)

Consolidated Balance Sheet (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
CURRENT ASSETS
Cash and temporary cash investments	$ 394	$ 648
Accounts receivable - customers, less allowance for uncollectible accounts	1,222	1,123
Other receivables, less allowance for uncollectible accounts	228	303
Accrued unbilled revenue	516	474
Fuel oil, gas in storage, materials and supplies, at average cost	330	356
Prepayments	159	145
Regulatory assets	74	164
Deferred tax assets - current	296	266
Other current assets	232	159
TOTAL CURRENT ASSETS	3,451	3,638
INVESTMENTS	467	455
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	555	89
Construction work in progress	83	39
NET PLANT	26,939	25,093
UTILITY PLANT, AT ORIGINAL COST
General	2,302	1,944
TOTAL	31,847	29,775
Less: Accumulated depreciation	6,573	6,051
Net	25,274	23,724
Construction work in progress	1,027	1,241
NET UTILITY PLANT	26,301	24,965
OTHER NONCURRENT ASSETS
Goodwill	429	429
Intangible assets, less accumulated amortization of $4 and $3 in 2012 and 2011, respectively	2	3
Regulatory assets	9,705	9,431
Other deferred charges and noncurrent assets	216	165
TOTAL OTHER NONCURRENT ASSETS	10,352	10,028
TOTAL ASSETS	41,209	39,214
CURRENT LIABILITIES
Long-term debt due within one year	706	530
Notes payable	539
Accounts payable	1,215	955
Customer deposits	304	303
Accrued taxes	162	188
Accrued interest	153	160
Accrued wages	94	91
Fair value of derivative liabilities	47	169
Regulatory liabilities	183	118
Other current liabilities	542	473
TOTAL CURRENT LIABILITIES	3,945	2,987
NONCURRENT LIABILITIES
Obligations under capital leases	2	2
Provision for injuries and damages	149	181
Pensions and retiree benefits	4,678	4,835
Superfund and other environmental costs	545	489
Asset retirement obligations	159	145
Fair value of derivative liabilities	31	48
Other noncurrent liabilities	125	131
TOTAL NONCURRENT LIABILITIES	5,689	5,831
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	8,372	7,563
Regulatory liabilities	1,202	977
Other deferred credits	70	64
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	9,644	8,604
LONG-TERM DEBT (See Statement of Capitalization)	10,062	10,143
SHAREHOLDERS' EQUITY
Common shareholders' equity (See Statement of Common Shareholder's Equity)	11,869	11,436
Preferred stock		213
TOTAL SHAREHOLDERS' EQUITY	11,869	11,649
Total Liabilities and Shareholders' Equity	41,209	39,214
Electric Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	22,376	21,114
Gas Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	5,120	4,734
Steam Plant [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,049	1,983
CECONY [Member]
CURRENT ASSETS
Cash and temporary cash investments	353	372
Accounts receivable - customers, less allowance for uncollectible accounts	1,108	977
Other receivables, less allowance for uncollectible accounts	106	102
Accrued unbilled revenue	406	366
Accounts receivable from affiliated companies	61	54
Fuel oil, gas in storage, materials and supplies, at average cost	285	308
Prepayments	81	85
Regulatory assets	60	140
Deferred tax assets - current	193	157
Other current assets	134	100
TOTAL CURRENT ASSETS	2,787	2,661
INVESTMENTS	207	177
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	6	6
NET PLANT	24,745	23,502
UTILITY PLANT, AT ORIGINAL COST
General	2,126	1,785
TOTAL	29,801	27,854
Less: Accumulated depreciation	6,009	5,523
Net	23,792	22,331
Construction work in progress	947	1,165
NET UTILITY PLANT	24,739	23,496
OTHER NONCURRENT ASSETS
Goodwill	245
Regulatory assets	8,972	8,750
Other deferred charges and noncurrent assets	174	128
TOTAL OTHER NONCURRENT ASSETS	9,146	8,878
TOTAL ASSETS	36,885	35,218
CURRENT LIABILITIES
Long-term debt due within one year	700	525
Notes payable	421
Accounts payable	989	774
Accounts payable to affiliated companies	22	16
Customer deposits	292	290
Accrued taxes	37	32
Accrued taxes to affiliated companies	215	126
Accrued interest	133	133
Accrued wages	84	81
Fair value of derivative liabilities	28	98
Regulatory liabilities	145	79
Other current liabilities	446	396
TOTAL CURRENT LIABILITIES	3,512	2,550
NONCURRENT LIABILITIES
Obligations under capital leases	2	2
Provision for injuries and damages	141	173
Pensions and retiree benefits	4,220	4,337
Superfund and other environmental costs	433	373
Asset retirement obligations	158	145
Fair value of derivative liabilities	11	24
Other noncurrent liabilities	115	120
TOTAL NONCURRENT LIABILITIES	5,080	5,174
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	7,452	6,921
Regulatory liabilities	1,077	861
Other deferred credits	67	61
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	8,596	7,843
LONG-TERM DEBT (See Statement of Capitalization)	9,145	9,220
SHAREHOLDERS' EQUITY
Common shareholders' equity (See Statement of Common Shareholder's Equity)	10,552	10,218
Preferred stock		213
TOTAL SHAREHOLDERS' EQUITY	10,552	10,431
Total Liabilities and Shareholders' Equity	36,885	35,218
CECONY [Member] \| Electric Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	21,079	19,886
CECONY [Member] \| Gas Transmission [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	4,547	4,200
CECONY [Member] \| Steam Plant [Member]
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,049	$ 1,983

Consolidated Balance Sheet (Parenthetical) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Accounts receivable - customers, allowance for uncollectible accounts	$ 94	$ 87
Other receivables, allowance for uncollectible accounts	10	10
Non-utility property, accumulated depreciation	68	59
Intangible assets, accumulated amortization	4	3
CECONY [Member]
Accounts receivable - customers, allowance for uncollectible accounts	87	79
Other receivables, allowance for uncollectible accounts	9	9
Non-utility property, accumulated depreciation	$ 25	$ 24

The cumulative amount of depreciation, depletion and amortization (related to property, plant and equipment, but not including land) that has been recognized in the income statement.

+ References+ Details

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, 2009	$ 10,249	$ 9,347	$ 30	$ 589	$ 4,420	$ 3,877	$ 6,904	$ 5,909	$ (1,001)	$ (62)	$ (62)	$ (42)	$ (4)	$ (962)
BALANCE (In Shares) at Dec. 31, 2009			281,123,741	235,488,094					23,210,700
Net income for common stock	992	893					992
Net Income	1,003	904						904
Common stock dividend	(676)	(670)					(676)	(670)
Issuance of common shares - public offering	306		1		307					(2)
Capital contribution by parent		355				357					(2)
Issuance of common shares - public offering (In Shares)			6,300,000
Cumulative preferred dividends	(11)	(11)						(11)
Issuance of common shares - dividend reinvestment and employee stock plans	188				188
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			4,192,593
Other comprehensive income	2	(2)										2	(2)
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	1,051	978					1,051
Net Income	1,062	989						989
Common stock dividend	(703)	(681)					(703)	(681)
Cumulative preferred dividends	(11)	(11)						(11)
Issuance of common shares - dividend reinvestment and employee stock plans	132		1		76				55
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			1,272,187						(1,538,166)
Common stock repurchases	(87)								(87)
Common stock repurchases(in Shares)									1,521,541
Other comprehensive income	(18)	(2)										(18)	(2)
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	292,888,521	235,488,094					23,194,075
Net income for common stock	1,138	1,014					1,138
Net Income	1,141	1,017						1,017
Common stock dividend	(709)	(682)					(709)	(682)
Cumulative preferred dividends	(3)	(3)						(3)
Issuance of common shares - dividend reinvestment and employee stock plans	(1)								(4)	3
Preferred stock redemption		3									3
Issuance of common shares - dividend reinvestment and employee stock plans (In Shares)			(16,625)						16,625
Other comprehensive income	5	(1)										5	(1)
BALANCE at Dec. 31, 2012	$ 11,869	$ 10,552	$ 32	$ 589	$ 4,991	$ 4,234	$ 7,997	$ 6,761	$ (1,037)	$ (61)	$ (61)	$ (53)	$ (9)	$ (962)
BALANCE (In Shares) at Dec. 31, 2012	292,871,896	235,488,094	292,871,896	235,488,094					23,210,700

Consolidated Statement of Capitalization (USD $) In Millions, except Share data, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
TOTAL COMMON SHAREHOLDERS' EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS	$ 11,922	$ 11,494
TOTAL COMMON SHAREHOLDERS' EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	292,871,896	292,888,521
Pension plan liability adjustments, net	(50)	(55)
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment	(3)	(3)
TOTAL ACCUMULATED OTHER COMPREHENSIVE LOSS, NET OF TAXES	(53)	(58)
TOTAL COMMON SHAREHOLDERS' EQUITY (SEE STATEMENT OF COMMON SHAREHOLDER'S EQUITY)	11,869	11,436
Preferred stock		213
CECONY [Member]
TOTAL COMMON SHAREHOLDERS' EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS	10,561	10,226
TOTAL COMMON SHAREHOLDERS' EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	235,488,094	235,488,094
Pension plan liability adjustments, net	(6)	(5)
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment	(3)	(3)
TOTAL ACCUMULATED OTHER COMPREHENSIVE LOSS, NET OF TAXES	(9)	(8)
TOTAL COMMON SHAREHOLDERS' EQUITY (SEE STATEMENT OF COMMON SHAREHOLDER'S EQUITY)	10,552	10,218
Preferred stock		213
Cumulative Preferred Stock [Member]
Preferred stock		175
Preferred stock (in shares)		1,915,319
Cumulative Preferred Stock [Member] \| CECONY [Member]
Preferred stock		175
Preferred stock (in shares)		1,915,319
4.65% Series C [Member] \| Cumulative Preferred Stock [Member]
Preferred stock		16
Preferred stock (in shares)		153,296
4.65% Series C [Member] \| Cumulative Preferred Stock [Member] \| CECONY [Member]
Preferred stock		16
Preferred stock (in shares)		153,296
4.65% Series D [Member] \| Cumulative Preferred Stock [Member]
Preferred stock		22
Preferred stock (in shares)		222,330
4.65% Series D [Member] \| Cumulative Preferred Stock [Member] \| CECONY [Member]
Preferred stock		$ 22
Preferred stock (in shares)		222,330

The total of net gain (loss), prior service cost (credit), and transition assets (obligations), as well as minimum pension liability if still remaining, included in accumulated other comprehensive income associated with a defined benefit pension or other postretirement plan(s) because they have yet to be recognized as components of net periodic benefit cost.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 14

-URI http://asc.fasb.org/extlink&oid=20435746&loc=d3e681-108580

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-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 11

-URI http://asc.fasb.org/extlink&oid=20435746&loc=d3e637-108580

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-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 14A

-URI http://asc.fasb.org/extlink&oid=20435746&loc=SL7669686-108580

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-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 10A

-Subparagraph (j-k)

-URI http://asc.fasb.org/extlink&oid=20435746&loc=SL7669646-108580

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 715

-SubTopic 20

-Section 50

-Paragraph 1

-Subparagraph (i)

-URI http://asc.fasb.org/extlink&oid=21915506&loc=d3e1928-114920

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 130

-Paragraph 26

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 158

-Paragraph 7

-Subparagraph c

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 132R

-Paragraph 5

-Subparagraph i

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+ Details

Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 14

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-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 11

-URI http://asc.fasb.org/extlink&oid=20435746&loc=d3e637-108580

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 220

-SubTopic 10

-Section 45

-Paragraph 14A

-URI http://asc.fasb.org/extlink&oid=20435746&loc=SL7669686-108580

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-Publisher AICPA

-Name Accounting Principles Board Opinion (APB)

-Number 12

-Paragraph 10

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-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 02

-Paragraph 31

-Article 5

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-Publisher FASB

-Name FASB Staff Position (FSP)

-Number FAS115-1/124-1

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Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 130

-Paragraph 14, 17, 26

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-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 04

-Article 3

+ Details

Aggregate par or stated value of issued nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer). This item includes treasury stock repurchased by the entity. Note: elements for number of nonredeemable preferred shares, par value and other disclosure concepts are in another section within stockholders' equity.

+ References+ Details

Consolidated Statement of Capitalization (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Pension plan liability adjustments, tax	$ (30)	$ (34)
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, tax and reclassification adjustment	(2)	(2)
Preferred stock, no par value	$ 0	$ 0
Preferred Stock, stated per share amount	$ 5	$ 5
Preferred stock, shares authorized	1,915,319	1,915,319
Preferred stock		213
Cumulative Preferred Stock [Member]
Preferred stock (in shares)		1,915,319
Preferred stock, shares authorized	6,000,000	6,000,000
Preferred stock, par value	$ 100	$ 100
Preferred stock		175
Cumulative Preferred Stock [Member] \| 4.65% Series C [Member]
Preferred stock (in shares)		153,296
Preferred stock		16
Cumulative Preferred Stock [Member] \| 4.65% Series D [Member]
Preferred stock (in shares)		222,330
Preferred stock		22
CECONY [Member]
Pension plan liability adjustments, tax	(4)	(3)
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, tax and reclassification adjustment	(2)	(2)
Preferred stock, no par value
Preferred Stock, stated per share amount	$ 5	$ 5
Preferred stock, shares authorized	1,915,319	1,915,319
Preferred stock		213
CECONY [Member] \| Cumulative Preferred Stock [Member]
Preferred stock (in shares)		1,915,319
Preferred stock		175
CECONY [Member] \| Cumulative Preferred Stock [Member] \| 4.65% Series C [Member]
Preferred stock (in shares)		153,296
Preferred stock, shares authorized	6,000,000	6,000,000
Preferred stock, par value	$ 100	$ 100
Preferred stock		16
CECONY [Member] \| Cumulative Preferred Stock [Member] \| 4.65% Series D [Member]
Preferred stock (in shares)		222,330
Preferred stock, shares authorized	6,000,000	6,000,000
Preferred stock		$ 22

Issuance value per share of no-par value, nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer); generally not indicative of the fair market value per share.

+ References+ Details

Face amount or stated value per share of nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer); generally not indicative of the fair market value per share.

+ References+ Details

Summary of Significant Accounting Policies

+ References+ Details

General	12 Months Ended
General	Dec. 31, 2012
General	General These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Con Edison’s other utility subsidiary, Orange and Rockland Utilities, Inc. (O&R), and Con Edison’s competitive energy businesses (discussed below) in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R. As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself. 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. 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.

Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2012

Note A — Summary of Significant Accounting Policies

Principles of Consolidation

The Companies’ consolidated financial statements include the accounts of their respective majority-owned subsidiaries, and variable interest entities (see Note Q), as required. All intercompany balances and transactions have been eliminated.

Accounting Policies

The accounting policies of Con Edison and its subsidiaries conform to accounting principles generally accepted in the United States of America. For the Utilities, these accounting principles include the accounting rules for regulated operations and the accounting requirements of the Federal Energy Regulatory Commission (FERC) and the state public utility regulatory commissions having jurisdiction.

The accounting rules for regulated operations specify the economic effects that result from the causal relationship of costs and revenues in the rate-regulated environment and how these effects are to be accounted for by a regulated enterprise. Revenues intended to cover some costs may be recorded either before or after the costs are incurred. If regulation provides assurance that incurred costs will be recovered in the future, these costs would be recorded as deferred charges or “regulatory assets” under the accounting rules for regulated operations. If revenues are recorded for costs that are expected to be incurred in the future, these revenues would be recorded as deferred credits or “regulatory liabilities” under the accounting rules for regulated operations.

The Utilities’ principal regulatory assets and liabilities are detailed in Note B. The Utilities are receiving or being credited with a return on all of their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on all of their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable public utility regulatory commission.

Other significant accounting policies of the Companies are referenced below in this Note A and in the notes that follow.

Plant and Depreciation

Utility Plant

Utility plant is stated at original cost. The cost of repairs and maintenance is charged to expense and the cost of betterments is capitalized. The capitalized cost of additions to utility plant includes indirect costs such as engineering, supervision, payroll taxes, pensions, other benefits and an allowance for funds used during construction (AFDC). The original cost of property is charged to expense over the estimated useful lives of the assets. Upon retirement, the original cost of property is charged to accumulated depreciation. See Note R.

Rates used for AFDC include the cost of borrowed funds and a reasonable rate of return on the Utilities’ own funds when so used, determined in accordance with regulations of the FERC or the state public utility regulatory authority having jurisdiction. The rate is compounded semiannually, and the amounts applicable to borrowed funds are treated as a reduction of interest charges, while the amounts applicable to the Utilities’ own funds are credited to other income (deductions). The AFDC rates for CECONY were 6.5 percent, 6.9 percent and 5.3 percent for 2012, 2011, and 2010, respectively. The AFDC rates for O&R were 7.0 percent, 6.6 percent and 5.8 percent for 2012, 2011, and 2010, respectively.

The Utilities generally compute annual charges for depreciation using the straight-line method for financial statement purposes, with rates based on average service lives and net salvage factors. The average depreciation rate for CECONY was 3.1 percent for 2012, 2011, and 2010. The average depreciation rate for O&R was 2.9 percent for 2012 and 2.8 percent for 2011 and 2010.

The estimated lives for utility plant for CECONY range from 5 to 80 years for electric, 5 to 85 years for gas, 5 to 70 years for steam and 5 to 50 years for general plant. For O&R, the estimated lives for utility plant range from 5 to 75 years for electric, 5 to 75 years for gas and 5 to 50 years for general plant.

At December 31, 2012 and 2011, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Electric
Generation	$	434	$	400	$	434	$	400
Transmission		2,698		2,654		2,518		2,476
Distribution		14,658		13,805		13,930		13,125
Gas*		4,170		3,858		3,735		3,455
Steam		1,674		1,651		1,674		1,651
General		1,567		1,282		1,439		1,162
Held for future use		72		74		62		62
Construction work in progress		1,027		1,241		947		1,165
Net Utility Plant	$	26,300	$	24,965	$	24,739	$	23,496

*	Primarily distribution.

Under the Utilities’ current rate plans, the aggregate annual depreciation allowance in effect at December 31, 2012 was $935 million, including $888 million under CECONY’s electric, gas and steam rate plans that have been approved by the New York State Public Service Commission (NYSPSC).

Non-Utility Plant

Non-utility plant is stated at original cost and consists primarily of land, gas storage and solar facilities that are currently not used within electric, gas or steam utility operations. Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives, which range from 3 to 30 years.

Goodwill

In accordance with the accounting rules for goodwill and intangible assets, Con Edison is required to test goodwill for impairment annually. Goodwill is tested for impairment using a two-step approach. The first step of the goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, the second step is performed to measure the amount of impairment loss, if any. The second step requires a calculation of the implied fair value of goodwill. See Note K.

Impairments

In accordance with the accounting rules for impairment or disposal of long-lived assets, the Companies evaluate the impairment of long-lived assets, based on projections of undiscounted future cash flows, whenever events or changes in circumstances indicate that the carrying amounts of such assets may not be recoverable. In the event an evaluation indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are written down to their estimated fair value. No impairment charges were recognized in 2012, 2011 or 2010.

Revenues

The Utilities and Con Edison Solutions recognize revenues for energy service on a monthly billing cycle basis. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers. The Utilities and Con Edison Solutions accrue revenues at the end of each month for estimated energy service not yet billed to customers.

CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism under which the company’s actual energy delivery revenues are compared on a periodic basis, with the authorized delivery revenues and the difference accrued, with interest, for refund to, or recovery from, customers, as applicable. See “Rate Agreements” in Note B.

The NYSPSC requires utilities to record gross receipts tax revenues and expenses on a gross income statement presentation basis (i.e., included in both revenue and expense). The recovery of these taxes is generally provided for in the revenue requirement within each of the respective NYSPSC approved rate plans.

Recoverable Energy Costs

The Utilities generally recover all of their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state public utility commissions. If the actual energy supply costs for a given month are more or less than the amounts billed to customers for that month, the difference in most cases is recoverable from or refundable to customers. Differences between actual and billed electric and steam supply costs are generally deferred for charge or refund to customers during the next billing cycle (normally within one or two months). In addition, CECONY recovers the costs of its electric demand management program, in excess of the costs reflected in rates, as part of recoverable energy costs. For the Utilities’ gas costs, differences between actual and billed gas costs during the 12-month period ending each August are charged or refunded to customers during a subsequent 12-month period.

New York Independent System Operator (NYISO)

The Utilities purchase electricity through the wholesale electricity market administered by the NYISO. The difference between purchased power and related costs initially billed to the Utilities by the NYISO and the actual cost of power subsequently calculated by the NYISO is refunded by the NYISO to the Utilities, or paid to the NYISO by the Utilities. The reconciliation payments or receipts are recoverable from or refundable to the Utilities’ customers.

Certain other payments to or receipts from the NYISO are also subject to reconciliation, with shortfalls or amounts in excess of specified rate allowances recoverable from or refundable to customers. These include proceeds from the sale through the NYISO of transmission rights on CECONY’s transmission system (transmission congestion contracts or TCCs).

Temporary Cash Investments

Temporary cash investments are short-term, highly-liquid investments that generally have maturities of three months or less at the date of purchase. They are stated at cost, which approximates market. The Companies consider temporary cash investments to be cash equivalents.

Investments

Investments consist primarily of the investments of Con Edison’s competitive energy businesses, which are accounted for under the equity method (depending on the subsidiaries’ percentage ownership) or accounted for as leveraged leases in accordance with the accounting rules for leases. See Note J for a discussion of investments in Lease In/Lease Out transactions. Utilities’ investments are recorded at fair value and include the deferred income plan and supplemental retirement income plan trust owned life insurance assets.

Pension and Other Postretirement Benefits

The accounting rules for retirement benefits require an employer to recognize an asset or liability for the overfunded or underfunded status of its pension and other postretirement benefit plans. For a pension plan, the asset or liability is the difference between the fair value of the plan’s assets and the projected benefit obligation. For any other postretirement benefit plan, the asset or liability is the difference between the fair value of the plan’s assets and the accumulated postretirement benefit obligation. The accounting rules generally require employers to recognize all unrecognized prior service costs and credits and unrecognized actuarial gains and losses in accumulated other comprehensive income (OCI), net of tax. Such amounts will be adjusted as they are subsequently recognized as components of net periodic benefit cost or income pursuant to the current recognition and amortization provisions.

For the Utilities’ pension and other postretirement benefit plans, regulatory accounting treatment is generally applied in accordance with the accounting rules for regulated operations. Unrecognized prior service costs or credits and unrecognized actuarial gains and losses are recorded to regulatory assets or liabilities, rather than OCI. See Notes E and F.

The net periodic benefit costs are recognized in accordance with the accounting rules for retirement benefits. Investment gains and losses are recognized in expense over a 15-year period and other actuarial gains and losses are recognized in expense over a 10-year period, subject to the deferral provisions in the rate plans.

In accordance with the Statement of Policy issued by the NYSPSC and its current electric, gas and steam rate agreements, CECONY defers for payment to or recovery from customers the difference between such expenses and the amounts for such expenses reflected in rates. Generally, O&R also defers such difference pursuant to its rate plans. See Note B – Regulatory Matters.

The Companies calculate the expected return on pension and other postretirement benefit plan assets by multiplying the expected rate of return on plan assets by the market-related value (MRV) of plan assets at the beginning of the year, taking into consideration anticipated contributions and benefit payments that are to be made during the year. The accounting rules allow the MRV of plan assets to be either fair value or a calculated value that recognizes changes in fair value in a systematic and rational manner over not more than five years. The Companies use a calculated value when determining the MRV of the plan assets that adjusts for 20 percent of the difference between fair value and expected MRV of plan assets. This calculated value has the effect of stabilizing variability in assets to which the Companies apply the expected return.

Federal Income Tax

In accordance with the accounting rules for income taxes, the Companies have recorded an accumulated deferred federal income tax liability for temporary differences between the book and tax basis of assets and liabilities at current tax rates. In accordance with rate agreements, the Utilities have recovered amounts from customers for a portion of the tax liability they will pay in the future as a result of the reversal or “turn-around” of these temporary differences. As to the remaining tax liability, in accordance with the accounting rules for regulated operations, the Utilities have established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense. See Notes B and L. In 1993, the NYSPSC issued a Policy Statement approving accounting procedures consistent with the accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. See Note L.

Accumulated deferred investment tax credits are amortized ratably over the lives of the related properties and applied as a reduction to future federal income tax expense.

The Companies’ federal income tax returns reflect certain tax positions with which the Internal Revenue Service (IRS) does not or may not agree. See “Lease In/Lease Out Transactions” in Note J and “Uncertain Tax Positions” in Note L.

Con Edison and its subsidiaries file a consolidated federal income tax return. The consolidated income tax liability is allocated to each member of the consolidated group using the separate return method. Each member pays or receives an amount based on its own taxable income or loss in accordance with tax sharing agreements among the members of the consolidated group. Tax loss carryforwards are allocated in accordance with consolidated tax return regulations.

State Income Tax

Con Edison and its subsidiaries file a combined New York State Corporation Business Franchise Tax Return. Similar to a federal consolidated income tax return, the income of all entities in the combined group is subject to New York State taxation, after adjustments for differences between federal and New York law and apportionment of income among the states in which the company does business. Each member of the group pays or receives an amount based on its own New York State taxable income or loss.

Research and Development Costs

Generally research and development costs are charged to operating expenses as incurred. Research and development costs were as follows:


	For the Years Ended December 31,
(Millions of Dollars)	2012		2011		2010
Con Edison	$	21	$	23	$	23
CECONY		19		21		21

Reclassification

Certain prior year amounts have been reclassified to conform with the current year presentation.

Earnings Per Common Share

In accordance with the accounting rules for earnings per share, Con Edison presents basic and diluted earnings per share on the face of its consolidated income statement. Basic earnings per share (EPS) are calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.

Potentially dilutive securities for Con Edison consist of restricted stock units, deferred stock units and stock options for which the average market price of the common shares for the period was greater than the exercise price. See Note M.

Basic and diluted EPS for Con Edison are calculated as follows:


	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2010
Net income for common stock	$	1,138	$	1,051	$	992
Weighted average common shares outstanding – Basic		292.9		292.6		284.3
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.8		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		294.4		285.9
Net Income for common stock per common share – basic	$	3.88	$	3.59	$	3.49
Net Income for common stock per common share – diluted	$	3.86	$	3.57	$	3.47

The computation of diluted EPS for the years ended December 31, 2012 and 2010 exclude immaterial amounts of performance share awards which were not included because of their anti-dilutive effect. No such exclusions were required for the computation of diluted EPS for the year ended December 31, 2011.

Estimates

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

CECONY [Member]

Summary of Significant Accounting Policies

Note A — Summary of Significant Accounting Policies

Principles of Consolidation

Accounting Policies

Other significant accounting policies of the Companies are referenced below in this Note A and in the notes that follow.

Plant and Depreciation

Utility Plant

At December 31, 2012 and 2011, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Electric
Generation	$	434	$	400	$	434	$	400
Transmission		2,698		2,654		2,518		2,476
Distribution		14,658		13,805		13,930		13,125
Gas*		4,170		3,858		3,735		3,455
Steam		1,674		1,651		1,674		1,651
General		1,567		1,282		1,439		1,162
Held for future use		72		74		62		62
Construction work in progress		1,027		1,241		947		1,165
Net Utility Plant	$	26,300	$	24,965	$	24,739	$	23,496

*	Primarily distribution.

Non-Utility Plant

Goodwill

Impairments

Revenues

Recoverable Energy Costs

New York Independent System Operator (NYISO)

Temporary Cash Investments

Investments

Pension and Other Postretirement Benefits

Federal Income Tax

Accumulated deferred investment tax credits are amortized ratably over the lives of the related properties and applied as a reduction to future federal income tax expense.

State Income Tax

Research and Development Costs

Generally research and development costs are charged to operating expenses as incurred. Research and development costs were as follows:


	For the Years Ended December 31,
(Millions of Dollars)	2012		2011		2010
Con Edison	$	21	$	23	$	23
CECONY		19		21		21

Reclassification

Certain prior year amounts have been reclassified to conform with the current year presentation.

Earnings Per Common Share

Basic and diluted EPS for Con Edison are calculated as follows:


	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2010
Net income for common stock	$	1,138	$	1,051	$	992
Weighted average common shares outstanding – Basic		292.9		292.6		284.3
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.8		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		294.4		285.9
Net Income for common stock per common share – basic	$	3.88	$	3.59	$	3.49
Net Income for common stock per common share – diluted	$	3.86	$	3.57	$	3.47

Estimates

The entire disclosure for all significant accounting policies of the reporting entity.

+ References+ Details

Regulatory Matters

12 Months Ended

Dec. 31, 2012

Regulatory Matters

Note B — Regulatory Matters

Rate Agreements

CECONY — Electric

The NYSPSC’s March 2008 order and, as discussed below, its April 2009 order and the November 2009 Joint Proposal covering CECONY’s electric rates provided for the collection of a portion of the company’s electric revenues ($254 million for the rate year ended March 2010 and, rate year ended March 2011, $249 million on an annual basis) subject to potential refund to customers following NYSPSC review and completion of an investigation by the NYSPSC staff of the company’s capital expenditures during the April 2005 through March 2008 period for transmission and distribution utility plant (the 2005-2008 Capital Expenditure Review). In December 2009, the company established a $24 million regulatory liability for refund to customers with respect to this matter and recognized a $14 million (after-tax) charge in its 2009 consolidated financial statements. In March 2010, the NYSPSC issued an order approving a February 2010 Joint Proposal by the company and the NYSPSC staff relating to this matter pursuant to which the company, among other things, provided a $36 million credit to customer bills in 2010.

In April 2009, the NYSPSC adopted an order granting CECONY an electric rate increase, effective April 6, 2009, of $523 million. The NYSPSC ruling reflects the following major items:

•

A return on common equity of 10.0 percent, based on certain assumptions, including a common equity ratio of 48 percent and achievement by the company of unspecified austerity measures required by the NYSPSC that would result in avoided revenue requirements of $60 million;

•

continuation of the revenue decoupling mechanism (in 2009, the company increased revenues by $122 million pursuant to this mechanism and the corresponding provision of the March 2008 rate order);

•

a decrease to $120 million from $150 million in the level of annual revenues that, for purposes of setting rates, it is assumed the company will receive and retain from the sale of transmission rights on the company’s transmission system, with the difference between such actual revenues for the rate year and $120 million to be recoverable from or refundable to customers, as the case may be (in 2009, the company accrued $7 million of revenues under this provision and the corresponding provision of the March 2008 rate order);

•

reconciliation of the actual amount of pension and other postretirement benefit costs, environmental remediation expenses, property taxes and the cost of long-term debt to amounts reflected in rates (in 2009, the company deferred recognition of $36.4 million of expenses under these provisions and the corresponding provisions of the March 2008 rate order);

•

if actual generation, transmission, distribution and shared service plant expenditures (other than removal costs) and capital costs incurred to relocate facilities to accommodate government projects are less than amounts reflected in rates for the respective category of expenditures, the company will accrue a regulatory liability and reduce its revenues by the revenue requirement impact of the difference (i.e., return on investment, depreciation and income taxes) (in 2009, the company did not reduce revenues under these provisions and the corresponding provisions of the March 2008 rate order);

•

collection of a surcharge (in addition to the electric rate increase) from customers in connection with an increase (estimated at $198 million), effective April 2009, in a New York State assessment;

•

continuation of provisions for potential operations penalties of up to $152 million annually if certain customer service and system reliability performance targets are not met (in 2009, the company did not reduce revenues under these provisions and the corresponding provisions of the March 2008 rate order);

•

continuation of the collection of a portion (increased, to reflect higher capital costs, from $237 million collected in the rate year ended March 2009 to $254 million for the rate year ending March 2010) of an April 2008 rate increase subject to potential refund to customers following the 2005-2008 Capital Expenditure Review (see discussion above in this Note B of the February 2010 Joint Proposal). The portion collected is also subject to refund in the event the NYSPSC determines that some disallowance of costs the company has recovered is warranted to address potential impacts of alleged unlawful conduct by arrested employees and contractors (see “Other Regulatory Matters” below in this Note B); and

•

continuation of the rate provisions pursuant to which the company recovers its purchased power and fuel costs from customers.

In May 2009, the company filed with the NYSPSC the company’s plan with respect to austerity measures that would reduce the company’s revenue requirements during the rate year ending March 31, 2010 by $60 million. The company’s austerity plans include reductions in labor costs, including compensation and other employee benefits, deferral of expenditures for capital projects and operating and maintenance programs and other initiatives. These reductions collectively represent $47 million of the $60 million reduction sought by the NYSPSC. In May 2009, the company filed with the NYSPSC a request for rehearing of the NYSPSC’s April 2009 order with respect to its austerity provisions and certain other matters. Pursuant to the February 2010 Joint Proposal (discussed above in Note B), the company withdrew this request.

In November 2009, CECONY, the NYSPSC staff and other parties entered into a Joint Proposal with respect to the company’s May 2009 request to the NYSPSC for an increase in the rates the company can charge its customers for electric delivery service. The Joint Proposal, which was approved in March 2010, covers the three-year period April 2010 through March 2013 and provides for electric base rate increases of $420 million, effective April 2010 and 2011, and $287 million, effective April 2012, with an additional $134 million to be collected through a surcharge in the rate year ending March 2013. 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.

The Joint Proposal reflects the following major items:

•

A weighted average cost of capital of 7.76 percent, reflecting:

•

return on common equity of 10.15 percent, assuming achievement by the company of unspecified austerity measures that would result in reductions in operations and maintenance expenses of $27 million, $20 million and $13 million in the rate years ending March 2011, 2012 and 2013, respectively (the company did not achieve the unspecified austerity measures in the rate years ending March 2011 and 2012);

•

cost of long-term debt of 5.65 percent;

•

common equity ratio of 48 percent; and

•

average rate base of $14,887 million, $15,987 million and $16,826 million for the rate years ending March 2011, 2012 and 2013, respectively.

•

Deferral as a regulatory liability of the revenue requirement impact (i.e., return on investment, depreciation and income taxes) of the amount, if any, by which (A) actual average net plant balances allocable to the company’s electric business for (i) transmission and distribution, excluding municipal infrastructure support (T&D), (ii) generation, shared services and, subject to certain adjustments, municipal infrastructure support (Other) and (iii) a finance and supply chain enterprise resource project (ERP) are less than (B) amounts reflected in rates for the respective category for each rate year. The amounts reflected in rates are:


	Rate Year Ending March 31,
(Millions of Dollars)	2011		2012		2013
T&D	$	13,818	$	14,742	$	15,414
Other		1,487		1,565		1,650
ERP		-		25		115

•

Any deferral for T&D and Other for the rate year ending March 2011 will be based on average net plant balances for the year and for the rate years ending March 2012 and 2013 will be based on average net plant balances over the term of the Joint Proposal. The company deferred $8 million and $0.1 million as a regulatory liability pursuant to this provision in 2011 and 2012, respectively.

•

Any deferral for ERP would be based on average net plant balances for ERP over the term of the Joint Proposal.

•

During the term of the Joint Proposal, the company will not accrue any additional revenue for carrying charges on any capital expenditures allocable to its electric business in excess of specified limits (which limits exclude certain expenditures, including expenditures for projects for which the company has been selected to receive grants under the American Recovery and Reinvestment Act of 2009):

•

T&D capital expenditures — $1,200 million for the rate year ending March 2011 and an aggregate $2,300 million for the period from April 2011 through March 2013 (such capital expenditures for the rate year ended March 2011 were less than $1,200 million);

•

Other capital expenditures — $220 million for the rate year ending March 2011 and an aggregate $402 million for the period from April 2011 through March 2013 (such capital expenditures for the rate year ended March 2011 were less than $220 million); and

•

ERP capital expenditures — $125 million (such capital expenditures for the rate year ended March 2011 were less than $125 million).

•

The company is not precluded from seeking to recover in rates effective after March 2013 the annual revenue requirement for T&D and Other capital expenditures made during the term of the Joint Proposal in excess of the applicable capital expenditure limit; provided that:

•

the company can justify the need for and reasonableness of, and the company’s inability to reasonably avoid, such excess capital expenditures; and

•

the return on investment for any such excess T&D or Other capital expenditures made during the rate year ending March 2011 will be calculated based on the company’s overall cost of debt. There were no such excess expenditures for the rate years ended March 2011 and 2012.

•

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

•

for the rate year ending March 2011, the company will allocate to customers the revenue requirement equivalent of 50 percent of earnings above 11.15 percent up to and including 12.149 percent, 75 percent of earnings equal to or in excess of 12.15 percent up to and including 13.149 percent and 90 percent of earnings equal to or in excess of 13.15 percent (earnings were not above 11.15 percent for the rate year ended March 2011);

•

for the rate years ending March 2012 and 2013, the company will allocate to customers the revenue requirement equivalent of 60 percent of the earnings, calculated on a cumulative basis for such years, in excess of 10.65 percent up to and including 12.149 percent, 75 percent of such cumulative earnings equal to or in excess of 12.15 percent up to and including 13.149 percent and 90 percent of such cumulative earnings equal to or in excess of 13.15 percent (earnings were not above 10.65 percent for the rate year ended March 2012);

•

the customers’ share of any such earnings and 50 percent of the company’s share would be applied to reduce regulatory assets for pensions and other postretirement benefits and other costs; and

•

because the company did not file for a rate increase to take effect in April 2013, the earnings sharing levels for the rate year ending March 2013 will continue in effect until base rates are reset by the NYSPSC.

•

Deferral as a regulatory asset or liability, as the case may be, of differences between the actual level of certain expenses, including, among others, expenses for pension and other postretirement benefits, environmental remediation, relocation of facilities to accommodate government projects, property taxes and (for the rate years ending March 2012 and 2013) long-term debt, and amounts for those expenses reflected in rates (with deferral for the difference in property taxes limited to 80 percent of the difference, subject to annual maximum for the remaining 20 percent of the difference of not more than a 10 basis point impact on return on common equity and deferral of facility relocation expenses in excess amounts reflected in rates subject to certain limitations). In 2010 and 2011, the company deferred $264 million as a net regulatory asset and $39 million as a net regulatory liability, respectively, under these provisions and the corresponding provisions of the April 2009 rate order.

•

Continuation of the provisions in the April 2009 order relating to revenues from the sale of transmission rights on the company’s transmission system. In 2010, 2011 and 2012, the company accrued $9 million, $26 million and $45 million of revenues, respectively, under this provision and the corresponding provision of the April 2009 rate order.

•

Continuation of the revenue decoupling mechanism under which the company’s actual electric delivery revenues would be compared, on a periodic basis, with the delivery revenues reflected in rates, and the difference accrued as a regulatory liability (for refund to electric customers) or a regulatory asset (for recovery from electric customers), as the case may be. In 2010, 2011 and 2012, the company deferred for customer benefit $124 million, $90 million and $59 million of revenues, respectively, under this provision and the corresponding provision of the April 2009 rate order.

•

Continuation of the rate provisions pursuant to which the company recovers its purchased power and fuel costs from electric customers.

•

Continuation of provisions for potential operations penalties of up to $152 million annually if certain electric customer service and system reliability performance targets are not met. In 2010 and 2012, the company did not recognize any expenses under these provisions and the corresponding provisions of the April 2009 order. In 2011, the company recognized a $5 million system reliability penalty.

•

Collection from electric customers of $249 million on an annual basis subject to potential refund following the 2005-2008 Capital Expenditure Review (see discussion above in this Note B of the February 2010 Joint Proposal). The amount to be collected would also be subject to refund in the event the NYSPSC determined that some disallowance of costs the company has recovered is warranted to address potential impacts of alleged unlawful conduct by arrested employees and contractors (see “Other Regulatory Matters” below in this Note B).

In January 2013, CECONY filed a request with the NYSPSC for an electric rate increase of $375 million, effective January 2014. The filing reflects a return on common equity of 10.35 percent and a common equity ratio of approximately 50 percent.

The company is requesting the implementation of programs to strengthen the storm resiliency of its electric infrastructure, as well as implementation of a surcharge mechanism to facilitate cost recovery for additional hardening programs as they may arise in the future. The company also is requesting continuation of provisions pursuant to which expenses for pension and other postretirement benefits, long-term debt, storms, the impact of new laws and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is requesting reconciliation of property taxes and municipal infrastructure support costs which, unlike the current provisions, would provide for full reconciliation of such costs. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers.

The filing includes supplemental information regarding electric rate plans for 2015 and 2016, which the company is not requesting but would consider through settlement discussions. For purposes of illustration, rate increases of $195 million and $270 million effective January 2015 and 2016, respectively, were calculated based upon an assumed return on common equity of 10.85 percent and a common equity ratio of approximately 50 percent.

O&R — Electric

In July 2008, the NYSPSC approved a Joint Proposal among O&R, the NYSPSC staff and other parties for the rates O&R can charge its New York customers for electric service from July 2008 through June 2011. The rate plan approved by the NYSPSC provides for electric rate increases of $15.6 million, $15.6 million and $5.7 million effective July 1, 2008, 2009 and 2010, respectively, and the collection of an additional $9.9 million during the 12-month period beginning July 1, 2010.

The Joint Proposal reflected the following major items:

•

an annual return on common equity of 9.4 percent;

•

most of any actual earnings above a 10.2 percent return on equity (based on actual average common equity ratio, subject to a 50 percent maximum) are to be applied to reduce regulatory assets for pension and other postretirement benefit expenses (the company did not reduce regulatory assets under this provision in 2011, 2010 or 2009);

•

deferral as a regulatory asset or regulatory liability, as the case may be, of the difference between actual pension and other postretirement benefit expenses, environmental remediation expenses, property taxes, tax-exempt debt costs and certain other expenses and amounts for those expenses reflected in rates (the company deferred recognition of $0.3 million of expenses, $0.7 million of revenue and $3 million of expenses under this provision in 2011, 2010, and 2009, respectively);

•

deferral as a regulatory liability of the revenue requirement impact (i.e., return on investment, depreciation and income taxes) of the amount, if any, by which actual transmission and distribution related capital expenditures are less than amounts reflected in rates (the company deferred $7 million, $12 million, and $8 million of revenues under this provision in 2011, 2010, and 2009, respectively);

•

deferral as a regulatory asset of increases, if any, in certain expenses above a 4 percent annual inflation rate, but only if the actual annual return on common equity is less than 9.4 percent (the company did not defer any expenses under this provision in 2011, 2010 or 2009);

•

potential negative earnings adjustments of up to $3 million annually if certain customer service and system reliability performance targets are not met (the company met the performance targets in 2011 and 2009; the company reduced revenues by $1 million under this provision in 2010);

•

implementation of a revenue decoupling mechanism under which actual energy delivery revenues would be compared, on a periodic basis, with the authorized delivery revenues with the difference accrued, with interest, for refund to, or recovery from, customers, as applicable (the company accrued $3.3 million, $5.1 million, and $12.5 million of revenues pursuant to this provision in 2011, 2010, and 2009, respectively);

•

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

•

withdrawal of the litigation O&R commenced seeking to annul the NYSPSC’s March and October 2007 orders relating to O&R’s electric rates.

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

•

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

•

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

•

cost of long-term debt of 5.50 percent; and

•

common equity ratio of 48 percent.

•

continuation of a revenue decoupling mechanism;

•

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

•

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

•

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

•

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

•

continuation of provisions for potential operations penalties of up to $3 million annually if certain customer service and system reliability performance targets are not met (in 2011, O&R did not recognize any operations penalties under these provisions or the corresponding provisions of the Joint Proposal discussed above); and

•

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

In February 2012, O&R, the staff of the NYSPSC and the Utility Intervention Unit of the New York State Department of State 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 postretirement 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 (in 2012, O&R did not recognize any operations penalties).

In March 2007, the New Jersey Board of Public Utilities (NJBPU) approved a three-year electric base rate plan for Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary that went into effect on April 1, 2007. The plan provides for a $6.4 million rate increase during the first year, with no further increase during the final two years. The plan reflects a return on common equity of 9.75 percent and a common equity ratio of 46.5 percent of capitalization.

In May 2010, RECO, the Division of Rate Counsel, Staff of the NJBPU and certain other parties entered into a stipulation of settlement with respect to the company’s August 2009 request to increase the rates that it can charge its customers for electric delivery service. The stipulation, which was approved by the Board of the NJBPU, provides for an electric rate increase, effective May 17, 2010, of $9.8 million. The stipulation reflects a return on common equity of 10.3 percent and a common equity ratio of approximately 50 percent. The stipulation continues current provisions with respect to recovery from customers of the cost of purchased power and does not provide for reconciliation of actual expenses to amounts reflected in electric rates for pension and other postretirement benefit costs. The stipulation requires RECO to file a base rate case by December 1, 2013.

CECONY — Gas

In September 2007, the NYSPSC approved the Joint Proposal that CECONY had entered into in June 2007 with the staff of the NYSPSC and other parties with respect to the rates the company can charge its customers for gas service. The Joint Proposal had provided for rate increases of $84.6 million, $32.7 million and $42.7 million, effective October 1, 2007, 2008 and 2009, respectively, along with annual funding for new energy efficiency programs of $14 million. The NYSPSC modified the Joint Proposal to provide for levelized annual rate increases of $67.5 million in each year of the three year rate plan.

The Joint Proposal continues the previous gas rate plan provisions with respect to recovery from customers of the cost of purchased gas and environmental remediation expenses and corresponding provisions pursuant to which the effects of weather on gas income are moderated and for the reconciliation of actual expenses allocable to the gas business to the amounts for such costs reflected in gas rates for pension and other postretirement benefit costs, property taxes and interference costs. Additional provisions of the gas rate plan include: a revenue decoupling mechanism (pursuant to which the company accrued $24 million, $25 million, and $17 million of revenues in 2010, 2009, and 2008, respectively) and equal sharing with customers of earnings above a 10.7 percent return on common equity (earnings for the rate years ended September 30, 2010, 2009 and 2008 were reduced $6 million, $0 and $9 million, respectively, for earnings above the 10.7 percent threshold).

In September 2010, the NYSPSC adopted the Joint Proposal among CECONY, the staff of the NYSPSC and other parties, with respect to the company’s rates for gas delivery service. The Joint Proposal provides for gas base rate increases of $47.1 million, $47.9 million and $46.7 million, effective October 2010, 2011 and 2012, respectively. The Joint Proposal reflects the following major items:

•

A weighted average cost of capital of 7.46 percent, reflecting:

•

return on common equity of 9.6 percent, assuming achievement by the company of cost avoidance for productivity and “austerity”. The unspecified austerity measures assume reductions in costs of $6 million, $4 million and $2 million in the rate years ending September 2011, 2012 and 2013, respectively;

•

cost of long-term debt of 5.57 percent;

•

common equity ratio of 48 percent; and

•

average rate base of $3,027 million, $3,245 million and $3,434 million for the rate years ending September 2011, 2012 and 2013, respectively.

•

Deferral as a regulatory liability of the revenue requirement impact (i.e., return on investment, depreciation and income taxes) of the amount, if any, by which actual average net plant balances allocable to the company’s gas business are less than the amounts reflected in rates: $2,934 million, $3,148 million and $3,346 million for the rate years ending September 2011, 2012 and 2013, respectively. No such deferral was required for the rate years ended September 2011 and 2012.

•

Sharing with gas customers of any actual earnings, excluding the effects of any penalties and certain other items, above specified percentage returns on equity (based on actual average common equity ratio, subject to a 50 percent maximum), on a cumulative basis over the term of the Joint Proposal, calculated as follows:

•

for the rate year ending September 2011, the company will allocate to customers the revenue requirement equivalent of 60 percent of earnings above 10.35 percent up to and including 11.59 percent, 75 percent of earnings equal to or in excess of 11.6 percent up to and including 12.59 percent and 90 percent of earnings equal to or in excess of 12.6 percent (earnings were not above 10.35 percent for the rate year ended September 2011);

•

for the rate years ending September 2012 and 2013, the company will allocate to customers the revenue requirement equivalent of 60 percent of the earnings in excess of 10.1 percent up to and including 11.59 percent, 75 percent of such earnings equal to or in excess of 11.6 percent up to and including 12.59 percent and 90 percent of such earnings equal to or in excess of 12.6 percent (earnings were not above 10.1 percent for the rate year ended September 2012);

•

the customers’ share of any such earnings and 50 percent of the company’s share, appropriately adjusted for taxes, would be applied to reduce regulatory assets for pensions and other postretirement benefits and other costs; and

•

because the company did not file for a rate increase to take effect in October 2013, the earnings sharing levels for the rate year ending September 2013 will continue in effect until base rates are reset by the NYSPSC.

•

Deferral as a regulatory asset or liability, as the case may be, of differences between the actual level of certain expenses, including, among others, expenses for pension and other postretirement benefits, environmental remediation, property taxes and long-term debt, and amounts for those expenses reflected in rates (with deferral for the difference in property taxes limited to 80 percent of the difference, subject to an annual maximum for the remaining 20 percent of the difference of not more than the equivalent in revenue requirement of a 10 basis point impact on return on common equity). In 2010, 2011 and 2012, the company deferred $67 million of net regulatory assets, $0.3 million of net regulatory liabilities and $46 million of net regulatory assets, respectively, under these provisions and the corresponding provisions of the September 2007 rate order.

•

Continuation of provisions pursuant to which the company will retain net revenues from non-firm customer transactions. In each year of the rate plan, the company will retain up to $58 million of any such revenues and 25 percent of any such revenues above $58 million. If such revenues are below $58 million in a rate year, the company will accrue a regulatory asset equal to (A) the amount by which such revenues are less than $33 million plus (B) 80 percent of the difference between $58 million and the level of such revenues at or above $33 million. The company retained $40 million, $70 million and $57 million of such net revenues in 2010, 2011 and 2012, respectively, under these provisions and the corresponding provisions of the September 2007 rate order.

•

Continuation of the provisions pursuant to which the effects of weather on gas delivery revenues during each billing cycle are reflected in customer bills for that billing cycle, and a revenue decoupling mechanism under which the company’s actual gas delivery revenues, inclusive of any such weather adjustment, would be compared, on a periodic basis, with the delivery revenues reflected in rates, with the difference accrued as a regulatory liability (for refund to gas customers) or a regulatory asset (for recovery from gas customers), as the case may be. In 2010, 2011 and 2012, the company deferred $14 million of regulatory assets, $20 million of regulatory liabilities and $22 million of regulatory liabilities, respectively, under this provision and the corresponding provisions of the September 2007 rate order.

•

Continuation of the rate provisions pursuant to which the company recovers its costs of purchased gas from gas customers.

•

Continuation of provisions for potential penalties (up to $12.6 million annually) if certain gas customer service and system performance targets are not met. In 2010, 2011 and 2012, the company did not recognize any expenses under these provisions or the corresponding provisions of the September 2007 rate order.

•

Continued collection from gas customers of $32 million on an annual basis subject to potential refund (see “Other Regulatory Matters” below).

In January 2013, CECONY filed a request with the NYSPSC for a gas rate increase of $25 million, effective January 2014. The filing reflects a return on common equity of 10.35 percent and a common equity ratio of approximately 50 percent.

The company is requesting the implementation of programs to strengthen the storm resiliency of its gas infrastructure, as well as implementation of a surcharge mechanism to facilitate cost recovery for additional hardening programs as they may arise in the future. The company is also requesting continuation of the current gas rate plan’s revenue decoupling mechanism and provisions with respect to recovery from customers of the cost of purchased gas and the reconciliation of actual expenses allocable to the gas business to the amounts for such expenses reflected in gas rates for pension and other postretirement benefits, long-term debt, the impact of new laws and environmental remediation expenses. In addition, the company is requesting reconciliation for property taxes and municipal infrastructure support costs (which, unlike the current provisions, would provide for full reconciliation of such costs) and the implementation of a gas storm cost reconciliation mechanism.

The filing includes supplemental information regarding gas rate plans for 2015 and 2016, which the company is not requesting but would consider through settlement discussions. For purposes of illustration, rate increases of $55 million and $63 million effective January 2015 and 2016, respectively, were calculated based upon an assumed return on common equity of 10.85 percent and a common equity ratio of approximately 50 percent.

O&R — Gas

In October 2009, the NYSPSC adopted a June 2009 Joint Proposal among O&R, NYSPSC staff and other parties. As approved, the Joint Proposal establishes a gas rate plan that covers the three-year period November 1, 2009 through October 31, 2012 and provides for increases in base rates of $9 million in each of the first two years and $4.6 million in the third year, with an additional $4.3 million to be collected through a surcharge in the third rate year. The rate plan reflects the following major items:

•

an annual return on common equity of 10.4 percent;

•

most of any actual earnings above an 11.4 percent annual return on common equity (based upon the actual average common equity ratio, subject to a maximum 50 percent of capitalization) are to be applied to reduce regulatory assets (in 2010, 2011 and 2012, the company did not defer any revenues under this provision);

•

deferral as a regulatory asset or liability, as the case may be, of differences between the actual level of certain expenses, including expenses for pension and other postretirement benefits, environmental remediation, property taxes and taxable and tax-exempt long-term debt, and amounts for those expenses reflected in rates (in 2010, 2011 and 2012, the company deferred $3.1 million, $2.9 million and $0.7 million, respectively, of expenses under this provision);

•

deferral as a regulatory liability of the revenue requirement impact (i.e., return on investment, depreciation and income taxes) of the amount, if any, by which average gas net plant balances are less than balances reflected in rates (in 2010, 2011 and 2012, the company deferred $1.5 million of revenues, and $1 million and $0.7 million of expenses, respectively, under this provision);

•

deferral as a regulatory asset of increases, if any over the course of the rate plan, in certain expenses above a 4 percent annual inflation rate, but only if the actual annual return on common equity is less than 10.4 percent (in 2010, 2011 and 2012, the company did not defer any revenues under this provision);

•

implementation of a revenue decoupling mechanism (in 2010, 2011 and 2012, the company accrued $0.8 million, $2.8 million and $4.7 million, respectively, of revenues under this provision);

•

continuation of the provisions pursuant to which the company recovers its cost of purchasing gas and the provisions pursuant to which the effects of weather on gas income are moderated; and

•

potential negative earnings adjustments of up to $1.4 million annually if certain operations and customer service requirements are not met (in 2010, 2011 and 2012, the company did not have any potential negative earnings adjustments under this provision).

•

because the company did not file for a rate increase to take effect in November 2012, the earnings sharing levels for the rate year ending October 2012 will continue in effect until base rates are reset by the NYSPSC.

CECONY — Steam

In September 2008, the NYSPSC approved the June 2008 Joint Proposal among the company, the NYSPSC staff and other parties with respect to the rates the company can charge its customers for steam service. The Joint Proposal covers the period from October 1, 2008 through September 30, 2010. The Joint Proposal provides for steam rate increases of $43.7 million effective October 1, 2008 and 2009.

The Joint Proposal reflects the following major items:

•

an annual return on common equity of 9.3 percent;

•

any actual earnings above a 10.1 percent return on equity (based on actual average common equity ratio, subject to a 50 percent maximum) are to be shared as follows: half will be deferred for the benefit of customers and the other half is to be retained by the company (with half of the company’s share subject to offset to reduce any regulatory assets for under-collections of property taxes) (earnings for the rate years ended September 30, 2009 and 2010 did not exceed a 10.1 percent return on equity);

•

deferral as a regulatory asset or regulatory liability, as the case may be, of the difference between (i) actual costs for pension and other postretirement benefits, environmental remediation, property taxes, certain tax-exempt debt, municipal infrastructure support and certain other costs and (ii) amounts for those costs reflected in rates (90 percent of the difference in the case of property taxes and interference costs) (the company decreased expenses by $14.9 million and $14.4 million and increased expenses by $3.1 million under these provisions in 2010, 2009 and 2008, respectively);

•

deferral as a regulatory liability of the revenue requirement impact (i.e., return on investment, depreciation and income taxes) of the amount, if any, by which the actual capital expenditures related to steam production plant are less than amounts reflected in rates (there was no regulatory liability recorded for the rate year ended September 30, 2009 and $4 million regulatory liability recorded for the rate year ended September 30, 2010);

•

potential negative earnings adjustments (revenue reductions) of approximately $0.95 million to $1 million annually if certain business development, customer service and safety performance targets are not met (the company did not record any such adjustments for the rate years ended September 30, 2010, 2009 and 2008);

•

amortization of certain regulatory assets and liabilities, the net effect of which will be a non-cash increase in steam revenues of $20.3 million over the two-year period covered by the Joint Proposal; and

•

continuation of the rate provisions pursuant to which the company recovers its fuel and purchased steam costs from customers.

In May 2010, CECONY, the NYSPSC staff and other parties entered into a Joint Proposal, with respect to the company’s rates for steam service. The Joint Proposal, which was approved by the NYSPSC in September 2010, covers the three-year period October 2010 through September 2013 and provides for rate increases of $49.5 million, effective October 2010 and 2011, and $17.8 million, effective October 2012, with an additional $31.7 million to be collected through a surcharge in the rate year ending September 2013. The Joint Proposal reflects the following major items:

•

The same weighted average cost of capital, return on common equity (assuming, for the steam business, achievement of unspecified reductions in costs of $4.5 million, $3 million and $1.5 million in the rate years ending September 2011, 2012 and 2013, respectively), cost of long-term debt and common equity ratio provided for in the May 2010 Joint Proposal with respect to CECONY’s gas business (discussed above) and average steam rate base of $1,589 million, $1,603 million and $1,613 million for the rate years ending September 2011, 2012 and 2013, respectively.

•

Deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net plant balances allocable to the company’s steam business are less than the amounts reflected in rates for the respective category for each rate year. The company deferred $0.3 million in 2011 and reduced its liability by $0.2 million in 2012. The amounts reflected in rates are:


	Rate Year Ending September 30,
(Millions of Dollars)	2011		2012		2013
Steam production	$	415	$	426	$	433
Steam distribution		521		534		543

•

Earnings sharing, expense deferral and potential refund ($6 million annually for steam) provisions as discussed above with respect to CECONY’s gas business. In 2011 and 2012, the company did not recognize any such earnings sharing, expense deferral or potential refund.

•

Continuation of the rate provisions pursuant to which the company recovers its cost of fuel and purchased steam from its steam customers.

•

Continuation of provisions for potential penalties (up to approximately $1 million annually) if certain steam customer service and system performance targets are not met. In 2011 and 2012, the company did not recognize any expense under these provisions.

In December 2012, as required by the NYSPSC order, CECONY proposed a phase-in over a period of not more than seven years of an increase in the allocation to steam customers of the fuel costs for the company’s East River Repowering Project (ERRP, which cogenerates electricity and steam) that are above the market value of the electric energy generated by ERRP.

In January 2013, CECONY filed a request with the NYSPSC for a steam rate decrease of $5 million, effective January 2014. The filing reflects a return on common equity of 10.35 percent and a common equity ratio of approximately 50 percent.

The company is requesting the implementation of programs to strengthen the storm resiliency of its steam infrastructure, as well as implementation of a surcharge mechanism to facilitate cost recovery for additional hardening programs as they may arise in the future. The company is also requesting implementation of weather normalization of revenues for steam and the continuation of provisions with respect to recovery from customers of the cost of fuel and purchased steam and the reconciliation of actual expenses allocable to the steam business to the amounts for such expenses reflected in steam rates for pension and other postretirement benefits, long-term debt, the impact of new laws and environmental remediation expenses. In addition, the company is requesting reconciliation for property taxes and municipal infrastructure support costs (which, unlike the current provisions, would provide for full reconciliation of such costs) and the implementation of a steam storm cost reconciliation mechanism.

The filing includes supplemental information regarding steam rate plans for 2015 and 2016, which the company is not requesting but would consider through settlement discussions. For purposes of illustration, rate increases of $22 million and $18 million effective January 2015 and 2016, respectively, were calculated based upon an assumed return on common equity of 10.85 percent and a common equity ratio of approximately 50 percent.

Other Regulatory Matters

In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures

following the arrests of employees for accepting illegal payments from a construction contractor. Subsequently, additional employees were arrested for accepting illegal payments from materials suppliers and an engineering firm. The arrested employees were terminated by the company and have pled guilty or been convicted. 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. The amount of electric revenues collected subject to refund, which was established in a different proceeding (the 2005-2008 Capital Expenditure Review discussed under “Rate Agreements – CECONY – Electric,” above), and the amount of gas and steam revenues collected subject to refund were not established as indicative of the company’s potential liability in this proceeding. At December 31, 2012, the company had collected an estimated $1,103 million from customers subject to potential refund in connection with this proceeding. In January 2013, a NYSPSC consultant reported its estimate, with which the company does not agree, of $208 million of overcharges with respect to a substantial portion of the company’s construction expenditures from January 2000 to January 2009. The company is disputing the consultant’s estimate, including its determinations as to overcharges regarding specific construction expenditures it selected to review and its methodology of extrapolating such determinations over a substantial portion of the construction expenditures during this period. The NYSPSC’s consultant has not reviewed the company’s other expenditures. The company and NYSPSC staff anticipate exploring settlement negotiations in this proceeding, the schedule for which may be coordinated with the schedule for consideration of the company’s January 2013 request for new electric, gas and steam rate plans. At December 31, 2012, the company had a $14 million regulatory liability for refund to customers of amounts recovered from vendors, arrested employees and insurers 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 late October 2012, Superstorm Sandy caused extensive damage to the Utilities’ electric distribution system and interrupted service to approximately 1.4 million customers. Superstorm Sandy also damaged CECONY’s steam system and interrupted service to many of its steam customers. In 2012, CECONY and O&R incurred response and restoration costs for Superstorm Sandy of $363 million and $98 million, respectively (including capital expenditures of $104 million and $14 million, respectively). Most of the costs that were not capitalized were deferred for recovery as a regulatory asset under the Utilities’ electric rate plans. See “Regulatory Assets and Liabilities” below. 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. See “Rate Agreements — CECONY-Electric and O&R-Electric,” above. The NYSPSC, the New York State Attorney General and a commission appointed by the Governor of New York are investigating the preparation and performance of the Utilities in connection with Superstorm Sandy and other major storms.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2012 and 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	$	5,677	$	5,852	$	5,407	$	5,554
Future income tax		1,922		1,798		1,831		1,724
Environmental remediation costs		730		681		615		564
Deferred storm costs		432		128		309		80
Pension and other postretirement benefits deferrals		183		198		154		157
Revenue taxes		176		163		170		158
Net electric deferrals		102		121		102		121
Unamortized loss on reacquired debt		74		84		70		80
Surcharge for New York State assessment		73		90		68		82
Deferred derivative losses – long-term		40		60		20		44
O&R transition bond charges		39		44		-		-
Preferred stock redemption		29		-		29		-
Recoverable energy costs – long-term		23		14		23		14
Workers’ compensation		19		23		19		23
Property tax reconciliation		16		13		-		-
Other		170		162		155		149
Regulatory assets – long-term		9,705		9,431		8,972		8,750
Deferred derivative losses – current		69		164		60		140
Recoverable energy costs – current		5		-		-		-
Regulatory assets – current		74		164		60		140
Total Regulatory Assets	$	9,779	$	9,595	$	9,032	$	8,890
Regulatory liabilities
Allowance for cost of removal less salvage	$	503	$	448	$	420	$	372
Property tax reconciliation		187		35		187		35
Net unbilled revenue deferrals		136		104		136		104
World Trade Center settlement proceeds		62		62		62		62
Long-term interest rate reconciliation		62		30		62		30
Carrying charges on T&D net plant – electric and steam		31		38		13		14
Gas line losses		14		21		14		21
Expenditure prudence proceeding		14		11		14		11
Energy efficiency programs		5		22		6		20
Other		188		206		163		192
Regulatory liabilities – long-term		1,202		977		1,077		861
Refundable energy costs – current		82		51		48		12
Revenue decoupling mechanism		72		66		68		66
Electric surcharge offset		29		-		29		-
Deferred derivative gains – current		-		1		-		1
Regulatory liabilities – current		183		118		145		79
Total Regulatory Liabilities	$	1,385	$	1,095	$	1,222	$	940

“Unrecognized pension and other postretirement costs” represents the net regulatory asset associated with the accounting rules for retirement benefits. See Note A.

“Deferred storm costs” represent response and restoration costs, other than capital expenditures, in connection with Superstorm Sandy and other major storms that were deferred by the Utilities under their New York electric rate plans. See “Other Regulatory Matters,” above.

“Net electric deferrals” represents the remaining unamortized balance of certain regulatory assets and liabilities of CECONY that were combined effective April 1, 2010 and are being amortized to income over a ten year period, in accordance with CECONY’s March 2010 rate plan.

“Revenue taxes” represents the timing difference between taxes collected and paid by the Utilities to fund mass transportation.

Effective March 31, 2009, the NYSPSC authorized CECONY to accrue unbilled electric, gas and steam revenues. At December 31, 2012, CECONY has deferred the net margin on the unbilled revenues for the future benefit of customers by recording a regulatory liability of $136 million for the difference between the unbilled revenues and energy cost liabilities.

CECONY [Member]

Regulatory Matters

Note B — Regulatory Matters

Rate Agreements

CECONY — Electric

In April 2009, the NYSPSC adopted an order granting CECONY an electric rate increase, effective April 6, 2009, of $523 million. The NYSPSC ruling reflects the following major items:

•

continuation of the revenue decoupling mechanism (in 2009, the company increased revenues by $122 million pursuant to this mechanism and the corresponding provision of the March 2008 rate order);

•

collection of a surcharge (in addition to the electric rate increase) from customers in connection with an increase (estimated at $198 million), effective April 2009, in a New York State assessment;

•

continuation of the rate provisions pursuant to which the company recovers its purchased power and fuel costs from customers.

The Joint Proposal reflects the following major items:

•

A weighted average cost of capital of 7.76 percent, reflecting:

•

cost of long-term debt of 5.65 percent;

•

common equity ratio of 48 percent; and

•

average rate base of $14,887 million, $15,987 million and $16,826 million for the rate years ending March 2011, 2012 and 2013, respectively.

•


	Rate Year Ending March 31,
(Millions of Dollars)	2011		2012		2013
T&D	$	13,818	$	14,742	$	15,414
Other		1,487		1,565		1,650
ERP		-		25		115

•

Any deferral for ERP would be based on average net plant balances for ERP over the term of the Joint Proposal.

•

ERP capital expenditures — $125 million (such capital expenditures for the rate year ended March 2011 were less than $125 million).

•

the company can justify the need for and reasonableness of, and the company’s inability to reasonably avoid, such excess capital expenditures; and

•

the customers’ share of any such earnings and 50 percent of the company’s share would be applied to reduce regulatory assets for pensions and other postretirement benefits and other costs; and

•

Continuation of the rate provisions pursuant to which the company recovers its purchased power and fuel costs from electric customers.

•

O&R — Electric

The Joint Proposal reflected the following major items:

•

an annual return on common equity of 9.4 percent;

•

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

•

withdrawal of the litigation O&R commenced seeking to annul the NYSPSC’s March and October 2007 orders relating to O&R’s electric rates.

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

•

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

•

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

•

cost of long-term debt of 5.50 percent; and

•

common equity ratio of 48 percent.

•

continuation of a revenue decoupling mechanism;

•

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

•

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

•

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

•

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;

•

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

•

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 (in 2012, O&R did not recognize any operations penalties).

CECONY — Gas

•

A weighted average cost of capital of 7.46 percent, reflecting:

•

cost of long-term debt of 5.57 percent;

•

common equity ratio of 48 percent; and

•

average rate base of $3,027 million, $3,245 million and $3,434 million for the rate years ending September 2011, 2012 and 2013, respectively.

•

Deferral as a regulatory asset or liability, as the case may be, of differences between the actual level of certain expenses, including, among others, expenses for pension and other postretirement benefits, environmental remediation, property taxes and long-term debt, and amounts for those expenses reflected in rates (with deferral for the difference in property taxes limited to 80 percent of the difference, subject to an annual maximum for the remaining 20 percent of the difference of not more than the equivalent in revenue requirement of a 10 basis point impact on return on common equity). In 2010, 2011 and 2012, the company deferred $67 million of net regulatory assets, $0.3 million of net regulatory liabilities and $46 million of net regulatory assets, respectively, under these provisions and the corresponding provisions of the September 2007 rate order.

•

Continuation of the rate provisions pursuant to which the company recovers its costs of purchased gas from gas customers.

•

Continued collection from gas customers of $32 million on an annual basis subject to potential refund (see “Other Regulatory Matters” below).

O&R — Gas

•

an annual return on common equity of 10.4 percent;

•

implementation of a revenue decoupling mechanism (in 2010, 2011 and 2012, the company accrued $0.8 million, $2.8 million and $4.7 million, respectively, of revenues under this provision);

•

continuation of the provisions pursuant to which the company recovers its cost of purchasing gas and the provisions pursuant to which the effects of weather on gas income are moderated; and

•

CECONY — Steam

The Joint Proposal reflects the following major items:

•

an annual return on common equity of 9.3 percent;

•

continuation of the rate provisions pursuant to which the company recovers its fuel and purchased steam costs from customers.

•


	Rate Year Ending September 30,
(Millions of Dollars)	2011		2012		2013
Steam production	$	415	$	426	$	433
Steam distribution		521		534		543

•

Continuation of the rate provisions pursuant to which the company recovers its cost of fuel and purchased steam from its steam customers.

•

Other Regulatory Matters

In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2012 and 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	$	5,677	$	5,852	$	5,407	$	5,554
Future income tax		1,922		1,798		1,831		1,724
Environmental remediation costs		730		681		615		564
Deferred storm costs		432		128		309		80
Pension and other postretirement benefits deferrals		183		198		154		157
Revenue taxes		176		163		170		158
Net electric deferrals		102		121		102		121
Unamortized loss on reacquired debt		74		84		70		80
Surcharge for New York State assessment		73		90		68		82
Deferred derivative losses – long-term		40		60		20		44
O&R transition bond charges		39		44		-		-
Preferred stock redemption		29		-		29		-
Recoverable energy costs – long-term		23		14		23		14
Workers’ compensation		19		23		19		23
Property tax reconciliation		16		13		-		-
Other		170		162		155		149
Regulatory assets – long-term		9,705		9,431		8,972		8,750
Deferred derivative losses – current		69		164		60		140
Recoverable energy costs – current		5		-		-		-
Regulatory assets – current		74		164		60		140
Total Regulatory Assets	$	9,779	$	9,595	$	9,032	$	8,890
Regulatory liabilities
Allowance for cost of removal less salvage	$	503	$	448	$	420	$	372
Property tax reconciliation		187		35		187		35
Net unbilled revenue deferrals		136		104		136		104
World Trade Center settlement proceeds		62		62		62		62
Long-term interest rate reconciliation		62		30		62		30
Carrying charges on T&D net plant – electric and steam		31		38		13		14
Gas line losses		14		21		14		21
Expenditure prudence proceeding		14		11		14		11
Energy efficiency programs		5		22		6		20
Other		188		206		163		192
Regulatory liabilities – long-term		1,202		977		1,077		861
Refundable energy costs – current		82		51		48		12
Revenue decoupling mechanism		72		66		68		66
Electric surcharge offset		29		-		29		-
Deferred derivative gains – current		-		1		-		1
Regulatory liabilities – current		183		118		145		79
Total Regulatory Liabilities	$	1,385	$	1,095	$	1,222	$	940

“Unrecognized pension and other postretirement costs” represents the net regulatory asset associated with the accounting rules for retirement benefits. See Note A.

“Revenue taxes” represents the timing difference between taxes collected and paid by the Utilities to fund mass transportation.

Capitalization

12 Months Ended

Dec. 31, 2012

Capitalization

Note C — Capitalization

Common Stock

At December 31, 2012 and 2011, Con Edison owned all of the issued and outstanding shares of common stock of the Utilities and the competitive energy businesses. CECONY owns 21,976,200 shares of Con Edison stock, which it purchased prior to 2001 in connection with Con Edison’s stock repurchase plan. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity.

Capitalization of Con Edison

The outstanding capitalization for each of the Companies is shown on its Consolidated Statement of Capitalization, and for Con Edison includes the Utilities’ outstanding debt.

Preferred Stock of CECONY

In May 2012, CECONY redeemed all of its outstanding shares of $5 Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value).

Dividends

In accordance with NYSPSC requirements, the dividends that the Utilities generally pay are limited to not more than 100 percent of their respective income available for dividends calculated on a two-year rolling average basis. Excluded from the calculation of “income available for dividends” are non-cash charges to income resulting from accounting changes or charges to income resulting from significant unanticipated events. The restriction also does not apply to dividends paid in order to transfer to Con Edison proceeds from major transactions, such as asset sales, or to dividends reducing each utility subsidiary’s equity ratio to a level appropriate to its business risk.

Long-term Debt

Long-term debt maturing in the period 2013-2017 is as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	706	$	700
2014		481		475
2015		495		350
2016		731		650
2017		7		-

The Utilities have issued $494 million of tax-exempt debt through the New York State Energy Research and Development Authority (NYSERDA) that currently bear interest at a rate determined weekly and is subject to tender by bondholders for purchase by the Utilities.

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


	December 31,
(Millions of Dollars)	2012				2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison	$	10,768	$	12,935	$	10,673	$	12,744
CECONY	$	9,845	$	11,751	$	9,745	$	11,593

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $12,299 million and $636 million of the fair value of long-term debt at December 31, 2012 are classified as Level 2 and Level 3, respectively. For CECONY, $11,115 million and $636 million of the fair value of long-term debt at December 31, 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.

At December 31, 2012 and 2011, long-term debt of Con Edison included $25 million and $29 million, respectively, of Transition Bonds issued in 2004 by O&R’s New Jersey utility subsidiary through a special purpose entity.

Significant Debt Covenants

The significant debt covenants under the financing arrangements for the notes of Con Edison and the debentures of CECONY are obligations to pay principal and interest when due, covenants not to consolidate with or merge into any other corporation unless certain conditions are met and, for Con Edison’s notes, covenants that Con Edison shall continue its utility business in New York City and shall not permit Con Edison’s ratio of consolidated debt to consolidated capital to exceed 0.675 to 1. Con Edison’s notes are also subject to cross default provisions with respect to other indebtedness of Con Edison or its material subsidiaries having a then outstanding principal balance in excess of $100 million. CECONY’s debentures have no cross default provisions. The tax-exempt financing arrangements of the Utilities are subject to covenants for the CECONY debentures discussed above and the covenants discussed below. The Companies believe that they were in compliance with their significant debt covenants at December 31, 2012.

The tax-exempt financing arrangements involved the issuance of uncollateralized promissory notes of the Utilities to NYSERDA in exchange for the net proceeds of a like amount of tax-exempt bonds with substantially the same terms sold to the public by NYSERDA. The tax-exempt financing arrangements include covenants with respect to the tax-exempt status of the financing, including covenants with respect to the use of the facilities financed. The arrangements include provisions for the maintenance of liquidity and credit facilities, the failure to comply with which would, except as otherwise provided, constitute an event of default with respect to the debt to which such provisions applied.

The failure to comply with debt covenants would, except as otherwise provided, constitute an event of default with respect to the debt to which such provisions applied. If an event of default were to occur, the principal and accrued interest on the debt to which such event of default applied and, in the case of the Con Edison notes, a make-whole premium might and, in the case of certain events of default would, become due and payable immediately.

The liquidity and credit facilities currently in effect for the tax-exempt financing include covenants that the ratio of debt to total capital of the obligated utility will not at any time exceed 0.65 to 1 and that, subject to certain exceptions, the utility will not mortgage, lien, pledge or otherwise encumber its assets. Certain of the facilities also include as events of default, defaults in payments of other debt obligations in excess of specified levels ($150 million or $100 million for CECONY, depending on the facility).

CECONY [Member]

Capitalization

Note C — Capitalization

Common Stock

Capitalization of Con Edison

The outstanding capitalization for each of the Companies is shown on its Consolidated Statement of Capitalization, and for Con Edison includes the Utilities’ outstanding debt.

Preferred Stock of CECONY

In May 2012, CECONY redeemed all of its outstanding shares of $5 Cumulative Preferred Stock and Cumulative Preferred Stock ($100 par value).

Dividends

Long-term Debt

Long-term debt maturing in the period 2013-2017 is as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	706	$	700
2014		481		475
2015		495		350
2016		731		650
2017		7		-

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


	December 31,
(Millions of Dollars)	2012				2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison	$	10,768	$	12,935	$	10,673	$	12,744
CECONY	$	9,845	$	11,751	$	9,745	$	11,593

Significant Debt Covenants

Short-Term Borrowing	12 Months Ended
Short-Term Borrowing	Dec. 31, 2012
Short-Term Borrowing	Note D — Short-Term Borrowing In October 2011, Con Edison and the Utilities entered into a Credit Agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis. Under the Credit Agreement, which expires in October 2016, there is a maximum of $2.25 billion of credit available, with the full amount available to CECONY and $1 billion available to Con Edison, including up to $1.2 billion of letters of credit. The Credit Agreement supports the Companies’ commercial paper programs. The Companies have not borrowed under the Credit Agreement. At December 31, 2012, Con Edison had $539 million of commercial paper outstanding of which $421 million was outstanding under CECONY’s program. The weighted average interest rate was 0.3 percent for both Con Edison and CECONY. At December 31, 2011 Con Edison and CECONY had no commercial paper outstanding. The banks’ commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2012 this ratio was 0.49 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding 5 percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings. At December 31, 2012 and 2011, $131 million (including $121 million for CECONY) and $173 million (including $150 million for CECONY) of letters of credit were outstanding under the Credit Agreement. See Note S for information about short-term borrowing between related parties.
CECONY [Member]
Short-Term Borrowing	Note D — Short-Term Borrowing In October 2011, Con Edison and the Utilities entered into a Credit Agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis. Under the Credit Agreement, which expires in October 2016, there is a maximum of $2.25 billion of credit available, with the full amount available to CECONY and $1 billion available to Con Edison, including up to $1.2 billion of letters of credit. The Credit Agreement supports the Companies’ commercial paper programs. The Companies have not borrowed under the Credit Agreement. At December 31, 2012, Con Edison had $539 million of commercial paper outstanding of which $421 million was outstanding under CECONY’s program. The weighted average interest rate was 0.3 percent for both Con Edison and CECONY. At December 31, 2011 Con Edison and CECONY had no commercial paper outstanding. The banks’ commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2012 this ratio was 0.49 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding 5 percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings. At December 31, 2012 and 2011, $131 million (including $121 million for CECONY) and $173 million (including $150 million for CECONY) of letters of credit were outstanding under the Credit Agreement. See Note S for information about short-term borrowing between related parties.

The entire disclosure for short-term debt.

+ References+ Details

Pension Benefits

12 Months Ended

Dec. 31, 2012

Pension Benefits

Note E — Pension Benefits

Con Edison maintains a tax-qualified, non-contributory pension plan that covers substantially all employees of CECONY and O&R and certain employees of Con Edison’s competitive energy businesses. The plan is designed to comply with the Internal Revenue Code and the Employee Retirement Income Security Act of 1974. In addition, Con Edison maintains additional non-qualified supplemental pension plans.

Net Periodic Benefit Cost

The components of the Companies’ net periodic benefit costs for 2012, 2011, and 2010 were as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
Service cost – including administrative expenses	$	237		$	190		$	168		$	220		$	177		$	157
Interest cost on projected benefit obligation		547			560			556			513			524			521
Expected return on plan assets		(705	)		(734	)		(704	)		(670	)		(698	)		(670	)
Recognition of net actuarial loss		709			530			425			670			501			401
Recognition of prior service costs		8			8			8			6			6			6
NET PERIODIC BENEFIT COST	$	796		$	554		$	453		$	739		$	510		$	415
Amortization of regulatory asset*		2			2			2			2			2			2
TOTAL PERIODIC BENEFIT COST	$	798		$	556		$	455		$	741		$	512		$	417
Cost capitalized		(277	)		(185	)		(157	)		(260	)		(172	)		(146	)
Reconciliation to rate level		(8	)		(65	)		(115	)		(12	)		(68	)		(113	)
Cost charged to operating expenses	$	513		$	306		$	183		$	469		$	272		$	158

*	Relates to an increase in CECONY’s pension obligation of $45 million from a 1999 special retirement program.

Funded Status

The funded status at December 31, 2012, 2011, and 2010 was as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$	11,825		$	10,307		$	9,408		$	11,072		$	9,653		$	8,803
Service cost – excluding administrative expenses		224			186			160			209			174			149
Interest cost on projected benefit obligation		547			560			556			513			524			521
Plan amendments		-			-			6			-			-			-
Net actuarial loss		1,323			1,251			636			1,255			1,166			607
Benefits paid		(513	)		(479	)		(459	)		(477	)		(445	)		(427	)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$	13,406		$	11,825		$	10,307		$	12,572		$	11,072		$	9,653
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$	7,800		$	7,721		$	6,877		$	7,406		$	7,340		$	6,544
Actual return on plan assets		1,094			37			888			1,040			33			846
Employer contributions		785			542			443			729			498			404
Benefits paid		(513	)		(479	)		(459	)		(477	)		(445	)		(427	)
Administrative expenses		(31	)		(21	)		(28	)		(30	)		(20	)		(27	)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$	9,135		$	7,800		$	7,721		$	8,668		$	7,406		$	7,340
FUNDED STATUS	$	(4,271	)	$	(4,025	)	$	(2,586	)	$	(3,904	)	$	(3,666	)	$	(2,313	)
Unrecognized net loss	$	5,594		$	5,351		$	3,915		$	5,297		$	5,063		$	3,716
Unrecognized prior service costs		23			30			38			10			16			22
Accumulated benefit obligation		11,911			10,595			9,319			11,116			9,876			8,694

The increase in the pension plan’s projected benefit obligation was a primary driver in the increased pension liability at Con Edison and CECONY of $246 million and $238 million, respectively, compared with December 31, 2011. For Con Edison, this increase in pension liability resulted in an increase to regulatory assets of $233 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations and a debit to OCI of $1 million (net of taxes) for the unrecognized net losses and unrecognized prior service costs associated with the competitive energy businesses and O&R’s New Jersey and Pennsylvania utility subsidiaries.

For CECONY, the increase in pension liability resulted in an increase to regulatory assets of $225 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations and a debit to OCI of $1 million (net of taxes) for unrecognized net losses and unrecognized prior service costs associated with the competitive energy businesses.

A portion of the unrecognized net loss and prior service cost for the pension plan, equal to $837 million and $5 million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $792 million and $4 million, respectively, for CECONY.

At December 31, 2012 and 2011, Con Edison’s investments include $164 million and $129 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $148 million and $120 million, respectively. See Note P. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $231 million and $193 million as of December 31, 2012 and $208 million and $171 million as of December 31, 2011, respectively.

Assumptions

The actuarial assumptions were as follows:


	2012			2011			2010
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate		4.10	%		4.70	%		5.60	%
Rate of compensation increase
– CECONY		4.35	%		4.35	%		4.35	%
– O&R		4.25	%		4.25	%		4.25	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate		4.70	%		5.60	%		6.05	%
Expected return on plan assets		8.00	%		8.50	%		8.50	%
Rate of compensation increase
– CECONY		4.35	%		4.35	%		4.00	%
– O&R		4.25	%		4.25	%		4.00	%

The expected return assumption reflects anticipated returns on the plan’s current and future assets. The Companies’ expected return was based on an evaluation of the current environment, market and economic outlook, relationships between the economy and asset class performance patterns, and recent and long-term trends in asset class performance. The projections were based on the plan’s target asset allocation.

Discount Rate Assumption

To determine the assumed discount rate, the Companies use a model that produces a yield curve based on yields on selected highly rated (Aa or higher by either Moody’s Investors Service (Moody’s) or Standard & Poor’s) corporate bonds. Bonds with insufficient liquidity, bonds with questionable pricing information and bonds that are not representative of the overall market are excluded from consideration. For example, the bonds used in the model cannot be callable, they must have a price between 50 and 200, the yield must lie between 1 percent and 20 percent, and the amount of the bond issue outstanding must be in excess of $50 million. The spot rates defined by the yield curve and the plan’s projected benefit payments are used to develop a weighted average discount rate.

Expected Benefit Payments

Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years:


(Millions of Dollars)	2013		2014		2015		2016		2017		2018-2022
Con Edison	$	554	$	582	$	608	$	634	$	659	$	3,635
CECONY		517		542		567		591		614		3,394

Expected Contributions

Based on estimates as of December 31, 2012, the Companies expect to make contributions to the pension plan during 2013 of $893 million (of which $834 million is to be contributed by CECONY). The Companies’ policy is to fund their accounting cost to the extent tax deductible.

Plan Assets

The asset allocations for the pension plan at the end of 2012, 2011, and 2010, and the target allocation for 2013 are as follows:


	Target Allocation Range		Plan Assets at December 31
Asset Category	2013		2012			2011			2010
Equity Securities		55% - 65%		60	%		61	%		67	%
Debt Securities		27% - 33%		31	%		32	%		28	%
Real Estate		8% - 12%		9	%		7	%		5	%
Total		100%		100	%		100	%		100	%

Con Edison has established a pension trust for the investment of assets to be used for the exclusive purpose of providing retirement benefits to participants and beneficiaries and payment of plan expenses.

Pursuant to resolutions adopted by Con Edison’s Board of Directors, the Management Development and Compensation Committee of the Board of Directors (the Committee) has general oversight responsibility for Con Edison’s pension and other employee benefit plans. The pension plan’s named fiduciaries have been granted the authority to control and manage the operation and administration of the plans, including overall responsibility for the investment of assets in the trust and the power to appoint and terminate investment managers.

The investment objectives of the Con Edison pension plan are to maintain a level and form of assets adequate to meet benefit obligations to participants, to achieve the expected long-term total return on the trust assets within a prudent level of risk and maintain a level of volatility that is not expected to have a material impact on the Company’s expected contribution and expense or the Company’s ability to meet plan obligations. The assets of the plan have no significant concentration of risk in one country (other than the United States), industry or entity.

The strategic asset allocation is intended to meet the objectives of the pension plan by diversifying its funds across asset classes, investment styles and fund managers. An asset/liability study typically is conducted every few years to determine whether the current strategic asset allocation continues to represent the appropriate balance of expected risk and reward for the plan to meet expected liabilities. Each study considers the investment risk of the asset allocation and determines the optimal asset allocation for the plan. The target asset allocation for 2013 reflects the results of such a study conducted in 2011.

Individual fund managers operate under written guidelines provided by Con Edison, which cover such areas as investment objectives, performance measurement, permissible investments, investment restrictions, trading and execution, and communication and reporting requirements. Con Edison management regularly monitors, and the named fiduciaries review and report to the Committee regarding, asset class performance, total fund performance, and compliance with asset allocation guidelines. Management changes fund managers and rebalances the portfolio as appropriate. At the direction of the named fiduciaries, such changes are reported to the Committee.

Assets measured at fair value on a recurring basis are summarized below under a three-level hierarchy established by the accounting rules which define the levels within the hierarchy as follows:

•

Level 1 – Consists of fair value measurements whose value is based on quoted prices in active markets for identical assets or liabilities.

•

Level 2 – Consists of fair value measurements whose value is based on significant other observable inputs.

•

Level 3 – Consists of fair value measurements whose value is based on significant unobservable inputs.

The fair values of the pension plan assets at December 31, 2012 by asset category are as follows:


(Millions of Dollars)	Level 1			Level 2			Level 3			Total
U.S. Equity(a)	$	2,637		$	-		$	-		$	2,637
International Equity(b)		2,242			753			-			2,995
Private Equity(c)		-			-			20			20
U.S. Government Issues(d)		-			1,626			-			1,626
Corporate Bonds(e)		-			993			-			993
Structured Assets(f)		-			30			-			30
Other Fixed Income(g)		-			123			-			123
Real Estate(h)		-			-			833			833
Cash and Cash Equivalents(i)		83			328			-			411
Futures(j)		210			-			-			210
Total investments	$	5,172		$	3,853		$	853		$	9,878
Funds for retiree health benefits(k)		(185	)		(137	)		(31	)		(353	)
Investments (excluding funds for retiree health benefits)	$	4,987		$	3,716		$	822		$	9,525
Pending activities(l)											(390	)
Total fair value of plan net assets										$	9,135

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities.

(b)	International Equity includes international equity index funds and actively-managed international equities.

(c)	Private Equity consists of global equity funds that are not exchange-traded.

(d)	U.S. Government Issues include agency and treasury securities.

(e)	Corporate Bonds consist of debt issued by various corporations.

(f)	Structured Assets include commercial-mortgage-backed securities and collateralized mortgage obligations.

(g)	Other Fixed Income includes municipal bonds, sovereign debt and regional governments.

(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.

(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.

(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.

(k)

The Companies set aside funds for retiree health benefits through a separate account within the pension trust, as permitted under Section 401(h) of the Internal Revenue Code of 1986, as amended. In accordance with the Code, the plan’s investments in the 401(h) account may not be used for, or diverted to, any purpose other than providing health benefits for retirees. The net assets held in the 401(h) account are calculated based on a pro-rata percentage allocation of the net assets in the pension plan. The related obligations for health benefits are not included in the pension plan’s obligations and are included in the Companies’ other postretirement benefit obligation. See Note F.

(l)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2012 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2012			Assets Still Held at Reporting Date – Unrealized Gains/(Losses)			Assets Sold During the Period – Realized Gains			Purchases Sales and Settlements			Transfer in/(out) of Level 3			Ending Balance as of December 31, 2012
Real Estate	$	572		$	48		$	1		$	212		$	-		$	833
Private Equity		-			1			-			19			-			20
Corporate Bonds		94			-			-			(33	)		(61	)		-
Structured Assets		13			-			(6	)		-			(7	)		-
Other Fixed Income		29			-			-			(6	)		(23	)		-
Total investments	$	708		$	49		$	(5	)	$	192		$	(91	)	$	853
Funds for retiree health benefits		(28	)		(2	)		-			(4	)		3			(31	)
Investments (excluding funds for retiree health benefits)	$	680		$	47		$	(5	)	$	188		$	(88	)	$	822

The fair values of the pension plan assets at December 31, 2011 by asset category are as follows:


(Millions of Dollars)	Level 1			Level 2			Level 3			Total
U.S. Equity(a)	$	2,467		$	-		$	-		$	2,467
International Equity(b)		1,850			637			-			2,487
U.S. Government Issues(c)		-			1,570			-			1,570
Corporate Bonds(d)		-			668			94			762
Structured Assets(e)		-			-			13			13
Other Fixed Income(f)		-			67			29			96
Real Estate(g)		-			-			572			572
Cash and Cash Equivalents(h)		13			395			-			408
Futures(i)		93			48			-			141
Total investments	$	4,423		$	3,385		$	708		$	8,516
Funds for retiree health benefits(j)		(174	)		(134	)		(28	)		(336	)
Investments (excluding funds for retiree health benefits)	$	4,249		$	3,251		$	680		$	8,180
Pending activities(k)											(380	)
Total fair value of plan net assets										$	7,800

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities.

(b)	International Equity includes international equity index funds and actively-managed international equities.

(c)	U.S. Government Issues include agency and treasury securities.

(d)	Corporate Bonds classified as Level 3 include 144A illiquid securities.

(e)	Structured Assets include commercial-mortgage-backed securities and collateralized mortgage obligations.

(f)	Other Fixed Income includes municipal bonds, sovereign debt and regional governments.

(g)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.

(h)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.

(i)	Futures consist of exchange-traded financial contracts encompassing U.S. equity, International equity and U.S. Government indices.

(j)

(k)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2011 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2011			Assets Still Held at Reporting Date – Unrealized Gains/(Losses)			Assets Sold During the Period – Realized Gains		Purchases Sales and Settlements			Ending Balance as of December 31, 2011
Real Estate	$	398		$	65		$	-	$	109		$	572
Corporate Bonds		129			(9	)		11		(37	)		94
Other Fixed Income		66			(1	)		3		(39	)		29
Structured Assets		87			(1	)		2		(75	)		13
Total investments	$	680		$	54		$	16	$	(42	)	$	708
Funds for retiree health benefits		(30	)		3			1		(2	)		(28	)
Investments (excluding funds for retiree health benefits)	$	650		$	57		$	17	$	(44	)	$	680

The Companies also offer a defined contribution savings plan that covers substantially all employees and made contributions to the plan as follows:


	For the Years Ended December 31
(Millions of Dollars)	2012		2011		2010
Con Edison	$	23	$	23	$	19
CECONY		21		21		17

CECONY [Member]

Pension Benefits

Note E — Pension Benefits

Net Periodic Benefit Cost

The components of the Companies’ net periodic benefit costs for 2012, 2011, and 2010 were as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
Service cost – including administrative expenses	$	237		$	190		$	168		$	220		$	177		$	157
Interest cost on projected benefit obligation		547			560			556			513			524			521
Expected return on plan assets		(705	)		(734	)		(704	)		(670	)		(698	)		(670	)
Recognition of net actuarial loss		709			530			425			670			501			401
Recognition of prior service costs		8			8			8			6			6			6
NET PERIODIC BENEFIT COST	$	796		$	554		$	453		$	739		$	510		$	415
Amortization of regulatory asset*		2			2			2			2			2			2
TOTAL PERIODIC BENEFIT COST	$	798		$	556		$	455		$	741		$	512		$	417
Cost capitalized		(277	)		(185	)		(157	)		(260	)		(172	)		(146	)
Reconciliation to rate level		(8	)		(65	)		(115	)		(12	)		(68	)		(113	)
Cost charged to operating expenses	$	513		$	306		$	183		$	469		$	272		$	158

*	Relates to an increase in CECONY’s pension obligation of $45 million from a 1999 special retirement program.

Funded Status

The funded status at December 31, 2012, 2011, and 2010 was as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$	11,825		$	10,307		$	9,408		$	11,072		$	9,653		$	8,803
Service cost – excluding administrative expenses		224			186			160			209			174			149
Interest cost on projected benefit obligation		547			560			556			513			524			521
Plan amendments		-			-			6			-			-			-
Net actuarial loss		1,323			1,251			636			1,255			1,166			607
Benefits paid		(513	)		(479	)		(459	)		(477	)		(445	)		(427	)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$	13,406		$	11,825		$	10,307		$	12,572		$	11,072		$	9,653
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$	7,800		$	7,721		$	6,877		$	7,406		$	7,340		$	6,544
Actual return on plan assets		1,094			37			888			1,040			33			846
Employer contributions		785			542			443			729			498			404
Benefits paid		(513	)		(479	)		(459	)		(477	)		(445	)		(427	)
Administrative expenses		(31	)		(21	)		(28	)		(30	)		(20	)		(27	)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$	9,135		$	7,800		$	7,721		$	8,668		$	7,406		$	7,340
FUNDED STATUS	$	(4,271	)	$	(4,025	)	$	(2,586	)	$	(3,904	)	$	(3,666	)	$	(2,313	)
Unrecognized net loss	$	5,594		$	5,351		$	3,915		$	5,297		$	5,063		$	3,716
Unrecognized prior service costs		23			30			38			10			16			22
Accumulated benefit obligation		11,911			10,595			9,319			11,116			9,876			8,694

Assumptions

The actuarial assumptions were as follows:


	2012			2011			2010
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate		4.10	%		4.70	%		5.60	%
Rate of compensation increase
– CECONY		4.35	%		4.35	%		4.35	%
– O&R		4.25	%		4.25	%		4.25	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate		4.70	%		5.60	%		6.05	%
Expected return on plan assets		8.00	%		8.50	%		8.50	%
Rate of compensation increase
– CECONY		4.35	%		4.35	%		4.00	%
– O&R		4.25	%		4.25	%		4.00	%

Discount Rate Assumption

Expected Benefit Payments

Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years:


(Millions of Dollars)	2013		2014		2015		2016		2017		2018-2022
Con Edison	$	554	$	582	$	608	$	634	$	659	$	3,635
CECONY		517		542		567		591		614		3,394

Expected Contributions

Plan Assets

The asset allocations for the pension plan at the end of 2012, 2011, and 2010, and the target allocation for 2013 are as follows:


	Target Allocation Range		Plan Assets at December 31
Asset Category	2013		2012			2011			2010
Equity Securities		55% - 65%		60	%		61	%		67	%
Debt Securities		27% - 33%		31	%		32	%		28	%
Real Estate		8% - 12%		9	%		7	%		5	%
Total		100%		100	%		100	%		100	%

Assets measured at fair value on a recurring basis are summarized below under a three-level hierarchy established by the accounting rules which define the levels within the hierarchy as follows:

•

Level 1 – Consists of fair value measurements whose value is based on quoted prices in active markets for identical assets or liabilities.

•

Level 2 – Consists of fair value measurements whose value is based on significant other observable inputs.

•

Level 3 – Consists of fair value measurements whose value is based on significant unobservable inputs.

The fair values of the pension plan assets at December 31, 2012 by asset category are as follows:


(Millions of Dollars)	Level 1			Level 2			Level 3			Total
U.S. Equity(a)	$	2,637		$	-		$	-		$	2,637
International Equity(b)		2,242			753			-			2,995
Private Equity(c)		-			-			20			20
U.S. Government Issues(d)		-			1,626			-			1,626
Corporate Bonds(e)		-			993			-			993
Structured Assets(f)		-			30			-			30
Other Fixed Income(g)		-			123			-			123
Real Estate(h)		-			-			833			833
Cash and Cash Equivalents(i)		83			328			-			411
Futures(j)		210			-			-			210
Total investments	$	5,172		$	3,853		$	853		$	9,878
Funds for retiree health benefits(k)		(185	)		(137	)		(31	)		(353	)
Investments (excluding funds for retiree health benefits)	$	4,987		$	3,716		$	822		$	9,525
Pending activities(l)											(390	)
Total fair value of plan net assets										$	9,135

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities.

(b)	International Equity includes international equity index funds and actively-managed international equities.

(c)	Private Equity consists of global equity funds that are not exchange-traded.

(d)	U.S. Government Issues include agency and treasury securities.

(e)	Corporate Bonds consist of debt issued by various corporations.

(f)	Structured Assets include commercial-mortgage-backed securities and collateralized mortgage obligations.

(g)	Other Fixed Income includes municipal bonds, sovereign debt and regional governments.

(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.

(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.

(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.

(k)

(l)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2012 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2012			Assets Still Held at Reporting Date – Unrealized Gains/(Losses)			Assets Sold During the Period – Realized Gains			Purchases Sales and Settlements			Transfer in/(out) of Level 3			Ending Balance as of December 31, 2012
Real Estate	$	572		$	48		$	1		$	212		$	-		$	833
Private Equity		-			1			-			19			-			20
Corporate Bonds		94			-			-			(33	)		(61	)		-
Structured Assets		13			-			(6	)		-			(7	)		-
Other Fixed Income		29			-			-			(6	)		(23	)		-
Total investments	$	708		$	49		$	(5	)	$	192		$	(91	)	$	853
Funds for retiree health benefits		(28	)		(2	)		-			(4	)		3			(31	)
Investments (excluding funds for retiree health benefits)	$	680		$	47		$	(5	)	$	188		$	(88	)	$	822

The fair values of the pension plan assets at December 31, 2011 by asset category are as follows:


(Millions of Dollars)	Level 1			Level 2			Level 3			Total
U.S. Equity(a)	$	2,467		$	-		$	-		$	2,467
International Equity(b)		1,850			637			-			2,487
U.S. Government Issues(c)		-			1,570			-			1,570
Corporate Bonds(d)		-			668			94			762
Structured Assets(e)		-			-			13			13
Other Fixed Income(f)		-			67			29			96
Real Estate(g)		-			-			572			572
Cash and Cash Equivalents(h)		13			395			-			408
Futures(i)		93			48			-			141
Total investments	$	4,423		$	3,385		$	708		$	8,516
Funds for retiree health benefits(j)		(174	)		(134	)		(28	)		(336	)
Investments (excluding funds for retiree health benefits)	$	4,249		$	3,251		$	680		$	8,180
Pending activities(k)											(380	)
Total fair value of plan net assets										$	7,800

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities.

(b)	International Equity includes international equity index funds and actively-managed international equities.

(c)	U.S. Government Issues include agency and treasury securities.

(d)	Corporate Bonds classified as Level 3 include 144A illiquid securities.

(e)	Structured Assets include commercial-mortgage-backed securities and collateralized mortgage obligations.

(f)	Other Fixed Income includes municipal bonds, sovereign debt and regional governments.

(g)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.

(h)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.

(i)	Futures consist of exchange-traded financial contracts encompassing U.S. equity, International equity and U.S. Government indices.

(j)

(k)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2011 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2011			Assets Still Held at Reporting Date – Unrealized Gains/(Losses)			Assets Sold During the Period – Realized Gains		Purchases Sales and Settlements			Ending Balance as of December 31, 2011
Real Estate	$	398		$	65		$	-	$	109		$	572
Corporate Bonds		129			(9	)		11		(37	)		94
Other Fixed Income		66			(1	)		3		(39	)		29
Structured Assets		87			(1	)		2		(75	)		13
Total investments	$	680		$	54		$	16	$	(42	)	$	708
Funds for retiree health benefits		(30	)		3			1		(2	)		(28	)
Investments (excluding funds for retiree health benefits)	$	650		$	57		$	17	$	(44	)	$	680

The Companies also offer a defined contribution savings plan that covers substantially all employees and made contributions to the plan as follows:


	For the Years Ended December 31
(Millions of Dollars)	2012		2011		2010
Con Edison	$	23	$	23	$	19
CECONY		21		21		17

The entire disclosure for pension and other postretirement benefits.

Other Postretirement Benefits

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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-Name Statement of Financial Accounting Standard (FAS)

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+ Details

Other Postretirement Benefits

12 Months Ended

Dec. 31, 2012

Note F — Other Postretirement Benefits

The Utilities currently have contributory comprehensive hospital, medical and prescription drug programs for all retirees, their dependents and surviving spouses.

Net Periodic Benefit Cost

The components of the Companies’ net periodic postretirement benefit costs for 2012, 2011, and 2010 were as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
Service cost	$	26		$	26		$	24		$	21		$	20		$	19
Interest cost on accumulated other postretirement benefit obligation		73			83			91			63			72			80
Expected return on plan assets		(85	)		(88	)		(86	)		(75	)		(78	)		(78	)
Recognition of net actuarial loss		98			88			92			87			80			85
Recognition of prior service cost		(21	)		(10	)		(12	)		(18	)		(11	)		(14	)
Recognition of transition obligation		2			4			3			2			4			3
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	93		$	103		$	112		$	80		$	87		$	95
Cost capitalized		(32	)		(35	)		(39	)		(28	)		(29	)		(33	)
Reconciliation to rate level		20			14			4			16			13			1
Cost charged to operating expenses	$	81		$	82		$	77		$	68		$	71		$	63

Funded Status

The funded status of the programs at December 31, 2012, 2011, and 2010 were as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$	1,756		$	1,642		$	1,697		$	1,511		$	1,426		$	1,495
Service cost		26			25			24			21			20			19
Interest cost on accumulated postretirement benefit obligation		73			83			91			63			72			80
Amendments		(127	)		-			-			(89	)		-			-
Net actuarial loss/(gain)		(175	)		109			(68	)		(178	)		86			(77	)
Benefits paid and administrative expenses		(146	)		(144	)		(138	)		(134	)		(132	)		(126	)
Participant contributions		37			33			29			36			32			28
Medicare prescription subsidy		10			8			7			8			7			7
BENEFIT OBLIGATION AT END OF YEAR	$	1,454		$	1,756		$	1,642		$	1,238		$	1,511		$	1,426
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$	947		$	942		$	866		$	840		$	839		$	777
Actual return on plan assets		124			20			89			109			19			78
Employer contributions		83			84			96			71			74			85
Participant contributions		37			33			29			36			32			28
Benefits paid		(144	)		(132	)		(138	)		(134	)		(124	)		(129	)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$	1,047		$	947		$	942		$	922		$	840		$	839
FUNDED STATUS	$	(407	)	$	(809	)	$	(700	)	$	(316	)	$	(671	)	$	(587	)
Unrecognized net loss	$	251		$	563		$	483		$	197		$	496		$	440
Unrecognized prior service costs		(105	)		(1	)		(10	)		(84	)		(15	)		(26	)
Unrecognized net transition liability at January 1, 1993		-			4			7			-			4			7

Assumptions

The actuarial assumptions were as follows:


	2012			2011			2010
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY		3.75	%		4.55	%		5.40	%
O&R		4.05	%		4.55	%		5.40	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate		4.55%			5.40%			5.95%
Expected Return on Plan Assets		8.50%			8.50%			8.50%

Refer to Note E for descriptions of the basis for determining the expected return on assets, investment policies and strategies, and the assumed discount rate.

A one-percentage point change in the assumed health care cost trend rate would have the following effects at December 31, 2013:


	Con Edison					CECONY
	1-Percentage-Point
(Millions of Dollars)	Increase			Decrease		Increase			Decrease
Effect on accumulated other postretirement benefit obligation	$	(12	)	$	12	$	(31	)	$	27
Effect on service cost and interest cost components for 2012		-			-		(2	)		1

Expected Benefit Payments

Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years, net of receipt of governmental subsidies:


(Millions of Dollars)	2013		2014		2015		2016		2017		2018-2022
BENEFIT PAYMENTS
Con Edison	$	101	$	101	$	101	$	98	$	97	$	452
CECONY		91		90		89		87		86		389

Expected Contributions

Based on estimates as of December 31, 2012, Con Edison expects to make a contribution of $8 million, nearly all of which is for CECONY, to the other postretirement benefit plans in 2013.

Plan Assets

The asset allocations for CECONY’s other postretirement benefit plans at the end of 2012, 2011, and 2010, and the target allocation for 2013 are as follows:


	Target Allocation Range			Plan Assets at December 31
Asset Category	2013			2012			2011			2010
Equity Securities		57	% - 73%		62	%		62	%		67%
Debt Securities		26	% - 44%		38	%		38	%		33%
Total		100	%		100	%		100	%		100%

Refer to Note E for a discussion of Con Edison’s investment policy for its benefit plans.

The fair values of the plan assets at December 31, 2012 by asset category (see description of levels in Note E) are as follows:


(Millions of Dollars)	Level 1		Level 2		Level 3		Total
U.S. Equity(a)	$	127	$	184	$	-	$	311
International Equity(b)		-		124		-		124
Other Fixed Income(c)		-		229		-		229
Cash and Cash Equivalents(d)		-		23		-		23
Total investments	$	127	$	560	$	-	$	687
Funds for retiree health benefits(e)		185		137		31		353
Investments (including funds for retiree health benefits)	$	312	$	697	$	31	$	1,040
Pending activities(f)								7
Total fair value of plan net assets							$	1,047

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and commingled funds.

(b)	International Equity includes commingled international equity funds.

(c)	Other Fixed Income includes commingled funds, which are valued at Net Asset Value.

(d)	Cash and Cash Equivalents include short term investments and money markets.

(e)

(f)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received, and reflects adjustments for available estimates at year end.

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2012 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2012		Assets Still Held at Reporting Date – Unrealized Gains/(Losses)		Assets Sold During the Period – Realized (Losses)		Purchases Sales and Settlements		Transfers Out of Level 3			Ending Balance as of December 31, 2012
Other Fixed Income	$	-	$	-	$	-	$	-	$	-		$	-
Insurance Contracts		-				-		-		-			-
Total investments	$	-	$	-	$	-	$	-	$	-		$	-
Funds for retiree health benefits		28		2		-		4		(3	)		31
Investments (including funds for retiree health benefits)	$	28	$	2	$	-	$	4	$	(3	)	$	31

The fair values of the plan assets at December 31, 2011 by asset category (see description of levels in Note E) are as follows:


(Millions of Dollars)	Level 1		Level 2		Level 3		Total
U.S. Equity(a)	$	115	$	162	$	-	$	277
International Equity(b)		-		104		-		104
Other Fixed Income(c)		-		207		-		207
Cash and Cash Equivalents(d)		-		18		-		18
Total investments	$	115	$	491	$	-	$	606
Funds for retiree health benefits(e)		174		134		28		336
Investments (including funds for retiree health benefits)	$	289	$	625	$	28	$	942
Pending activities(f)								5
Total fair value of plan net assets							$	947

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and commingled funds.

(b)	International Equity includes commingled international equity funds.

(c)	Other Fixed Income includes commingled funds, which are valued at Net Asset Value.

(d)	Cash and Cash Equivalents include short term investments and money markets.

(e)

(f)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received, and reflects adjustments for available estimates at year end.

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2011 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2011		Assets Still Held at Reporting Date — Unrealized Gains/(Losses)			Assets Sold During the Period — Realized (Losses)			Purchases Sales and Settlements		Transfers Out of Level 3			Ending Balance as of December 31, 2011
Other Fixed Income	$	189	$	-		$	-		$	-	$	(189	)	$	-
Insurance Contracts		-		-			-			-		-			-
Total investments	$	189	$	-		$	-		$	-	$	(189	)	$	-
Funds for retiree health benefits		30		(3	)		(1	)		2		-			28
Investments (including funds for retiree health benefits)	$	219	$	(3	)	$	(1	)	$	2	$	(189	)	$	28

The entire disclosure for postemployment benefits, which may include supplemental unemployment benefits, obligations recognized for all types of benefits provided to former or inactive employees, their beneficiaries, and covered dependents after employment but before retirement. Disclosure may also include discussion that an obligation for postemployment benefits is not accrued in accordance with regulation only because the amount cannot be reasonably estimated.

+ References+ Details

Environmental Matters

12 Months Ended

Dec. 31, 2012

Environmental Matters

Note G — Environmental Matters

Superfund Sites

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

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

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

The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2012 and 2011 were as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued Liabilities:
Manufactured gas plant sites	$	462	$	422	$	351	$	307
Other Superfund Sites		83		67		82		66
Total	$	545	$	489	$	433	$	373
Regulatory assets	$	730	$	681	$	615	$	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.

Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites at December 31, 2012 and 2011 were as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred	$	31	$	39	$	26	$	35
Insurance recoveries received*		4		-		4		-

*	Reduced amount deferred for recovery from customers

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 December 31, 2012 and 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

The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2012 and 2011 were as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued Liabilities:
Manufactured gas plant sites	$	462	$	422	$	351	$	307
Other Superfund Sites		83		67		82		66
Total	$	545	$	489	$	433	$	373
Regulatory assets	$	730	$	681	$	615	$	564

Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites at December 31, 2012 and 2011 were as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred	$	31	$	39	$	26	$	35
Insurance recoveries received*		4		-		4		-

*	Reduced amount deferred for recovery from customers

Asbestos Proceedings


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued liability – asbestos suits	$	10	$	10	$	10	$	10
Regulatory assets – asbestos suits	$	10	$	10	$	10	$	10
Accrued liability – workers’ compensation	$	94	$	98	$	89	$	93
Regulatory assets – workers’ compensation	$	19	$	23	$	19	$	23

Other Material Contingencies

The entire disclosure for environmental loss contingencies, such as presence of hazardous waste, relevant information from reports issued by regulators, and estimated costs to achieve compliance with regulatory requirements. This element may be used for all of an entity's disclosures about environmental loss contingencies.

+ References+ Details

Other Material Contingencies

12 Months Ended

Dec. 31, 2012

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.

Other Contingencies

See “Other Regulatory Matters” in Note B and “Lease In/Lease Out Transactions” in Note J.

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 $859 million and $760 million at December 31, 2012 and 2011, respectively.

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


Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	716	$	25	$	62	$	803
Intra-company guarantees		15		-		1		16
Other guarantees		35		5		-		40
Total	$	766	$	30	$	63	$	859

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, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet.

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;

•

$8 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 December 31, 2012.

CECONY [Member]

Other Material Contingencies

Note H — Other Material Contingencies

Manhattan Steam Main Rupture

Other Contingencies

See “Other Regulatory Matters” in Note B and “Lease In/Lease Out Transactions” in Note J.

Guarantees

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


Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	716	$	25	$	62	$	803
Intra-company guarantees		15		-		1		16
Other guarantees		35		5		-		40
Total	$	766	$	30	$	63	$	859

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:

•

The entire disclosure for commitments and contingencies.

Electricity Purchase Agreements

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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-Paragraph 3

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

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-SubTopic 10

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Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Electricity Purchase Agreements

12 Months Ended

Dec. 31, 2012

Note I — Electricity Purchase Agreements

CECONY has long-term electricity purchase agreements with non-utility generators and others for generating capacity. The company recovers its purchased power costs in accordance with provisions approved by the NYSPSC. See “Recoverable Energy Costs” in Note A.

At December 31, 2012, the significant terms of the electricity purchase agreements were as follows:


Facility	Equity Owner	Plant Output (MW)		Contracted Output (MW)			Contract Start Date		Contract Term (Years)
Indian Point	Entergy Nuclear Power Marketing, LLC		1,299		350	*		August 2001		16
Independence	Sithe/Independence Power Partners, LP		1,254		697			November 1994		20
Linden Cogeneration	Cogen Technologies Linden Venture, LP		1,035		628			May 1992		25
Astoria Energy	Astoria Energy, LLC		640		500			May 2006		10
Selkirk	Selkirk Cogen Partners, LP		446		265			September 1994		20
Brooklyn Navy Yard	Brooklyn Navy Yard Cogeneration Partners, LP		322		263			November 1996		40
Indeck Corinth	Indeck Energy Services of Corinth, Inc.		147		132			July 1995		20

*	Contracted output will increase to 500 MW in 2013.

Assuming performance by the parties to the electricity purchase agreements, CECONY is obligated over the terms of the agreements to make capacity and other fixed payments.

The future capacity and other fixed payments under the contracts are estimated to be as follows:

(Millions of
Dollars)

2013

2014

2015

2016

2017

All Years

Thereafter

CECONY

507

446

229

165

110

933

For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the agreements for capacity, energy and other fixed payments in 2012, 2011, and 2010 were as follows:


	For the Years Ended December 31,
(Millions of Dollars)	2012		2011		2010
Linden	$	297	$	379	$	414
Indian Point		204		238		524
Selkirk		196		209		185
Astoria		181		225		223
Independence		127		121		119
Brooklyn Navy Yard		93		123		123
Indeck Corinth		66		77		68
Total	$	1,164	$	1,372	$	1,656

CECONY [Member]

Electricity Purchase Agreements

Note I — Electricity Purchase Agreements

At December 31, 2012, the significant terms of the electricity purchase agreements were as follows:


Facility	Equity Owner	Plant Output (MW)		Contracted Output (MW)			Contract Start Date		Contract Term (Years)
Indian Point	Entergy Nuclear Power Marketing, LLC		1,299		350	*		August 2001		16
Independence	Sithe/Independence Power Partners, LP		1,254		697			November 1994		20
Linden Cogeneration	Cogen Technologies Linden Venture, LP		1,035		628			May 1992		25
Astoria Energy	Astoria Energy, LLC		640		500			May 2006		10
Selkirk	Selkirk Cogen Partners, LP		446		265			September 1994		20
Brooklyn Navy Yard	Brooklyn Navy Yard Cogeneration Partners, LP		322		263			November 1996		40
Indeck Corinth	Indeck Energy Services of Corinth, Inc.		147		132			July 1995		20

*	Contracted output will increase to 500 MW in 2013.

Assuming performance by the parties to the electricity purchase agreements, CECONY is obligated over the terms of the agreements to make capacity and other fixed payments.

The future capacity and other fixed payments under the contracts are estimated to be as follows:

(Millions of
Dollars)

2013

2014

2015

2016

2017

All Years

Thereafter

CECONY

507

446

229

165

110

933


	For the Years Ended December 31,
(Millions of Dollars)	2012		2011		2010
Linden	$	297	$	379	$	414
Indian Point		204		238		524
Selkirk		196		209		185
Astoria		181		225		223
Independence		127		121		119
Brooklyn Navy Yard		93		123		123
Indeck Corinth		66		77		68
Total	$	1,164	$	1,372	$	1,656

Leases

12 Months Ended

Dec. 31, 2012

Leases

Note J – Leases

Con Edison’s subsidiaries lease electric generating and gas distribution facilities, other electric transmission and distribution facilities, office buildings and equipment. In accordance with the accounting rules for leases, these leases are classified as either capital leases, operating leases or leveraged leases. Most of the operating leases provide the option to renew at the fair rental value for future periods. Generally, it is expected that leases will be renewed or replaced in the normal course of business.

Capital leases: For ratemaking purposes capital leases are treated as operating leases; therefore, in accordance with the accounting rules for regulated operations, the amortization of the leased asset is based on the rental payments recovered from customers. The following assets under capital leases are included in the Companies’ consolidated balance sheets at December 31, 2012 and 2011:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
UTILITY PLANT
Common	$	3	$	8	$	2	$	6
Transmission		-		1		-		1
TOTAL	$	3	$	9	$	2	$	7

The accumulated amortization of the capital leases for Con Edison and CECONY was $1 million and $0.4 million, respectively at December 31, 2012, and $66 million and $65 million, respectively at December 31, 2011.

The future minimum lease commitments for the above assets are as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	-	$	-
2014		1		1
2015		1		1
2016		-		-
2017		-		-
All years thereafter		1		1
Total		3		3
Less: amount representing interest		1		1
Present value of net minimum lease payment	$	2	$	2

Operating leases: The future minimum lease commitments under the Companies’ non-cancelable operating lease agreements are as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	52	$	49
2014		47		43
2015		15		12
2016		14		11
2017		14		11
All years thereafter		91		71
Total	$	233	$	197

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 $(76) million at December 31, 2012 and $(55) million at December 31, 2011 and is comprised of a $228 million gross investment less $304 million of deferred tax liabilities at December 31, 2012 and $234 million gross investment less $289 million of deferred tax liabilities at December 31, 2011.

On audit of Con Edison’s tax return for 1997, the IRS disallowed 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 tax 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. In January 2013, the United States Court of Appeals for the Federal Circuit reversed the October 2009 trial court decision and disallowed the tax deductions claimed by the company relating to the 1997 LILO transaction. Con Edison plans to request the United States Court of Appeals to grant rehearing en banc of the January 2013 decision.

In connection with its audit of Con Edison’s federal income tax returns for 1998 through 2007, the IRS disallowed $416 million of tax deductions taken with respect to both LILO transactions. Con Edison has been 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 tax deductions taken with respect to both LILO transactions.

As a result of the January 2013 Court of Appeals decision, Con Edison expects to record an estimated charge of between $150 million and $170 million (after-tax) in the first quarter of 2013 to reflect the interest on disallowed federal and state income tax deductions and, as required by the accounting rules for leveraged lease transactions, the recalculation of the accounting effect of the LILO transactions. The transactions did not impact earnings in 2012, 2011 or 2010.

In January 2013, to defray interest charges, the company deposited $447 million with federal and state tax agencies relating primarily to the potential tax liability from these transactions in past tax years and interest thereon. The company estimates (based on current market values) that if it were to negotiate the termination of the transactions, it could receive cash proceeds of approximately $210 million (pre-tax), which amount could be higher or lower depending on the negotiations.

CECONY [Member]

Leases

Note J – Leases


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
UTILITY PLANT
Common	$	3	$	8	$	2	$	6
Transmission		-		1		-		1
TOTAL	$	3	$	9	$	2	$	7

The future minimum lease commitments for the above assets are as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	-	$	-
2014		1		1
2015		1		1
2016		-		-
2017		-		-
All years thereafter		1		1
Total		3		3
Less: amount representing interest		1		1
Present value of net minimum lease payment	$	2	$	2

Operating leases: The future minimum lease commitments under the Companies’ non-cancelable operating lease agreements are as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	52	$	49
2014		47		43
2015		15		12
2016		14		11
2017		14		11
All years thereafter		91		71
Total	$	233	$	197

Lease In/Lease Out Transactions

The entire disclosure for lessee entity's leasing arrangements including, but not limited to, all of the following: (a.) The basis on which contingent rental payments are determined, (b.) The existence and terms of renewal or purchase options and escalation clauses, (c.) Restrictions imposed by lease agreements, such as those concerning dividends, additional debt, and further leasing.

+ References+ Details

Goodwill	12 Months Ended
Goodwill	Dec. 31, 2012
Goodwill	Note K – Goodwill In 2012 and 2011, Con Edison completed impairment tests for its goodwill of $406 million related to the O&R merger, and determined that it was not impaired. For the impairment test, $245 million and $161 million of the goodwill were allocated to CECONY and O&R, respectively. In 2012 and 2011, Con Edison completed impairment tests for the goodwill of $23 million related to two energy services companies acquired by Con Edison Solutions and an interest in a gas storage company acquired by Con Edison Development, and determined that the goodwill was not impaired.
CECONY [Member]
Goodwill	Note K – Goodwill In 2012 and 2011, Con Edison completed impairment tests for its goodwill of $406 million related to the O&R merger, and determined that it was not impaired. For the impairment test, $245 million and $161 million of the goodwill were allocated to CECONY and O&R, respectively. In 2012 and 2011, Con Edison completed impairment tests for the goodwill of $23 million related to two energy services companies acquired by Con Edison Solutions and an interest in a gas storage company acquired by Con Edison Development, and determined that the goodwill was not impaired.

The entire disclosure for the aggregate amount of goodwill and a description of intangible assets, which may include (a) for amortizable intangible assets (also referred to as finite-lived intangible assets), the carrying amount, the amount of any significant residual value, and the weighted-average amortization period, (b) for intangible assets not subject to amortization (also referred to as indefinite-lived intangible assets), the carrying amount, and (c) the amount of research and development assets acquired and written off in the period, including the line item in the income statement in which the amounts written off are aggregated, if not readily apparent from the income statement. Also discloses (a) for amortizable intangibles assets in total and by major class, the gross carrying amount and accumulated amortization, the total amortization expense for the period, and the estimated aggregate amortization expense for each of the five succeeding fiscal years, (b) for intangible assets not subject to amortization the carrying amount in total and by major class, and (c) for goodwill, in total and for each reportable segment, the changes in the carrying amount of goodwill during the period (including the aggregate amount of goodwill acquired, the aggregate amount of impairment losses recognized, and the amount of goodwill included in the gain (loss) on disposal of a reporting unit). If any part of goodwill has not been allocated to a reportable segment, discloses the unallocated amount and the reasons for not allocating. For each impairment loss recognized related to an intangible asset (excluding goodwill), discloses: (a) a description of the impaired intangible asset and the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method for determining fair value, (c) the caption in the income statement or the statement of activities in which the impairment loss is aggregated, and (d) the segment in which the impaired intangible asset is reported. For each goodwill impairment loss recognized, discloses: (a) a description of the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method of determining the fair value of the associated reporting unit, and (c) if a recognized impairment loss is an estimate not finalized and the reasons why the estimate is not final. May also disclose the nature and amount of any significant adjustments made to a previous estimate of an impairment loss.

+ References+ Details

Income Tax

12 Months Ended

Dec. 31, 2012

Income Tax

Note L – Income Tax

The components of income tax are as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
State
Current	$	29		$	56		$	23		$	53		$	53		$	13
Deferred		97			63			106			53			55			100
Federal
Current		(13	)		53			(144	)		110			43			(139	)
Deferred		493			434			569			318			413			527
Amortization of investment tax credits		(6	)		(6	)		(6	)		(5	)		(6	)		(6	)
Total charge to income tax expense	$	600		$	600		$	548		$	529		$	558		$	495

The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows:


	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Deferred tax liabilities:
Depreciation	$	4,210		$	3,652		$	3,909		$	3,464
Regulatory asset – future income tax		2,061			1,971			1,962			1,891
Unrecognized pension and other postretirement costs		2,472			2,554			2,202			2,255
State income tax		1,060			920			897			811
Capitalized overheads		565			536			496			470
Pension		736			682			730			709
Investment tax credits		49			55			47			52
Other		931			743			528			467
Total deferred tax liabilities		12,084			11,113			10,771			10,119
Deferred tax assets:
Unrecognized pension and other postretirement costs		2,472			2,554			2,202			2,255
State income tax		382			336			357			309
Regulatory liability – future income tax		126			173			117			167
Other		1,028			753			836			624
Total deferred tax assets		4,008			3,816			3,512			3,355
Net deferred tax liabilities and investment tax credits	$	8,076		$	7,297		$	7,259		$	6,764
Deferred income taxes and investment tax credits – Noncurrent	$	8,372		$	7,563		$	7,452		$	6,921
Deferred tax assets – Current		(296	)		(266	)		(193	)		(157	)
Net deferred tax liabilities and investment tax credits	$	8,076		$	7,297		$	7,259		$	6,764

Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes is as follows:


	Con Edison									CECONY
(% of Pre-tax income)	2012			2011			2010			2012			2011			2010
STATUTORY TAX RATE
Federal		35	%		35	%		35	%		35	%		35	%		35	%
Changes in computed taxes resulting from:
State income tax		4			5			5			4			5			5
Cost of removal		(4	)		(4	)		(4	)		(4	)		(4	)		(4	)
Other		(1	)		-			(1	)		(1	)		-			(1	)
Effective Tax Rate		34	%		36	%		35	%		34	%		36	%		35	%

For federal income tax purposes, Con Edison has a net operating loss carryforward available of $11 million and $632 million from 2012 and 2011, respectively, primarily as a result of accelerated depreciation and storm related deductions, which if unused will expire in 2032 and 2031. Con Edison has recorded a deferred tax asset for its loss carryforward, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized.

For New York State income tax purposes, Con Edison has a net operating loss carryforward available from 2009 of $284 million, primarily as a result of repair allowance deductions discussed below. A deferred tax asset has been recognized for this New York State net operating loss that will not expire until 2029. A valuation allowance has not been provided; as it is more likely than not that the deferred tax asset will be realized.

Uncertain Tax Positions

Under the accounting rules for income taxes, an enterprise shall not recognize the tax benefit attributable to a tax position unless such position is more likely than not to be sustained upon examination by taxing authorities, including resolution of any related appeals and litigation processes, based solely on the technical merits of the position.

The IRS has essentially completed its field audits of the Con Edison’s federal income tax returns through 2011. Con Edison’s federal income tax returns for 1998 through 2011 reflect certain tax positions with which the IRS does not or may not agree. Any adjustments to federal income tax returns would result in changes to Con Edison’s New York state income tax returns. In addition, Con Edison’s state income tax returns for years beginning with 2006 remain open for examination.

The Companies’ 2011 and 2010 federal income tax returns reflect, among other things, an incremental current deduction for the costs of certain repairs to utility plant (the “repair allowance deductions”). Prior to 2009, Con Edison capitalized such costs and included these costs in depreciation expense in its federal income tax returns. At December 31, 2012, with respect to the repair allowance deductions, Con Edison recorded a liability for uncertain tax positions of $72 million ($66 million attributable to CECONY).

In August 2011, the IRS issued guidance regarding the use and evaluation of statistical samples and sampling estimates. This guidance provides a safe harbor method of determining whether certain expenditures for electric transmission and distribution property can be currently deducted for federal income tax purposes. No guidance was issued related to generation, gas, or steam property.

A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
Balance at January 1	$	130		$	93		$	86		$	114		$	79		$	92
Additions based on tax positions related to the current year		12			76			5			11			74			4
Additions based on tax positions of prior years		-			4			67			-			3			49
Reductions for tax positions of prior years		(57	)		(43	)		(4	)		(52	)		(42	)		(4	)
Settlements		1			-			(61	)		1			-			(62	)
Balance at December 31	$	86		$	130		$	93		$	74		$	114		$	79

At December 31, 2012, the Companies’ estimated liabilities for uncertain tax positions ($86 million for Con Edison and $74 million for CECONY) were classified on their respective consolidated balance sheets either as current liabilities ($44 million for Con Edison and $36 million for CECONY) or as a reduction to current deferred tax assets ($42 million for Con Edison and $38 million for CECONY). The Companies reasonably expect to resolve these uncertain tax positions with the IRS in the next 12 months.

The Companies recognize interest accrued related to the liability for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In 2012, 2011 and 2010, the Companies recognized an immaterial amount of interest and no penalties for uncertain tax positions in their consolidated income statements. At December 31, 2012 and 2011, the Companies recognized an immaterial amount of interest and no penalties in their consolidated balance sheets.

At December 31, 2012, the total amount of unrecognized tax benefits that, if recognized, would affect the Companies’ effective tax rate is $7 million ($1 million attributable to CECONY).

In January 2013, a federal appeals court reversed a trial court decision that had allowed deductions claimed by Con Edison relating to Con Edison Development’s LILO transactions. See Note J.

CECONY [Member]

Income Tax

Note L – Income Tax

The components of income tax are as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
State
Current	$	29		$	56		$	23		$	53		$	53		$	13
Deferred		97			63			106			53			55			100
Federal
Current		(13	)		53			(144	)		110			43			(139	)
Deferred		493			434			569			318			413			527
Amortization of investment tax credits		(6	)		(6	)		(6	)		(5	)		(6	)		(6	)
Total charge to income tax expense	$	600		$	600		$	548		$	529		$	558		$	495

The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows:


	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Deferred tax liabilities:
Depreciation	$	4,210		$	3,652		$	3,909		$	3,464
Regulatory asset – future income tax		2,061			1,971			1,962			1,891
Unrecognized pension and other postretirement costs		2,472			2,554			2,202			2,255
State income tax		1,060			920			897			811
Capitalized overheads		565			536			496			470
Pension		736			682			730			709
Investment tax credits		49			55			47			52
Other		931			743			528			467
Total deferred tax liabilities		12,084			11,113			10,771			10,119
Deferred tax assets:
Unrecognized pension and other postretirement costs		2,472			2,554			2,202			2,255
State income tax		382			336			357			309
Regulatory liability – future income tax		126			173			117			167
Other		1,028			753			836			624
Total deferred tax assets		4,008			3,816			3,512			3,355
Net deferred tax liabilities and investment tax credits	$	8,076		$	7,297		$	7,259		$	6,764
Deferred income taxes and investment tax credits – Noncurrent	$	8,372		$	7,563		$	7,452		$	6,921
Deferred tax assets – Current		(296	)		(266	)		(193	)		(157	)
Net deferred tax liabilities and investment tax credits	$	8,076		$	7,297		$	7,259		$	6,764

Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes is as follows:


	Con Edison									CECONY
(% of Pre-tax income)	2012			2011			2010			2012			2011			2010
STATUTORY TAX RATE
Federal		35	%		35	%		35	%		35	%		35	%		35	%
Changes in computed taxes resulting from:
State income tax		4			5			5			4			5			5
Cost of removal		(4	)		(4	)		(4	)		(4	)		(4	)		(4	)
Other		(1	)		-			(1	)		(1	)		-			(1	)
Effective Tax Rate		34	%		36	%		35	%		34	%		36	%		35	%

Uncertain Tax Positions

A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
Balance at January 1	$	130		$	93		$	86		$	114		$	79		$	92
Additions based on tax positions related to the current year		12			76			5			11			74			4
Additions based on tax positions of prior years		-			4			67			-			3			49
Reductions for tax positions of prior years		(57	)		(43	)		(4	)		(52	)		(42	)		(4	)
Settlements		1			-			(61	)		1			-			(62	)
Balance at December 31	$	86		$	130		$	93		$	74		$	114		$	79

At December 31, 2012, the total amount of unrecognized tax benefits that, if recognized, would affect the Companies’ effective tax rate is $7 million ($1 million attributable to CECONY).

In January 2013, a federal appeals court reversed a trial court decision that had allowed deductions claimed by Con Edison relating to Con Edison Development’s LILO transactions. See Note J.

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

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+ Details

Stock-Based Compensation

12 Months Ended

Dec. 31, 2012

Stock-Based Compensation

Note M — Stock-Based Compensation

The Companies may compensate employees and directors with, among other things, stock options, restricted stock units and contributions to a discount stock purchase plan. The Stock Option Plan provided for awards of stock options to officers and employees for up to 10 million shares of Con Edison common stock. The Long Term Incentive Plan (LTIP), among other things, provides for awards of restricted stock units, stock options and, to Con Edison’s non-officer directors, deferred stock units for up to 10 million shares of common stock (of which not more than four million shares may be restricted stock or stock units).

Shares of Con Edison common stock used to satisfy the Companies’ obligations with respect to stock-based compensation may be new (authorized, but unissued) shares, treasury shares or shares purchased in the open market. The Companies intend to use treasury shares to fulfill their stock-based compensation obligations for 2013.

Under the accounting rules for stock compensation, the Companies have recognized the cost of stock-based compensation as an expense using a fair value measurement method. The following table summarizes stock-based compensation expense recognized by the Companies in the period ended December 31, 2012, 2011, and 2010:


	Con Edison						CECONY
(Millions of Dollars)	2012		2011		2010		2012		2011		2010
Performance-based restricted stock	$	14	$	48	$	27	$	13	$	44	$	25
Restricted stock units		1		3		1		1		3		1
Non-officer director deferred stock compensation		1		1		1		1		1		1
Total	$	16	$	52	$	29	$	15	$	48	$	27
Income Tax Benefit	$	6	$	21	$	12	$	6	$	20	$	11

Stock Options

The Companies last issued stock options in 2006. The stock options generally vested over a three-year period and have a term of ten years. Options were granted at an exercise price equal to the fair market value of a common share when the option was granted. The Companies generally recognized compensation expense (based on the fair value of stock option awards) over the continuous service period in which the options vested. Awards to employees eligible for retirement were expensed in the month awarded.

The outstanding options are “equity awards” because shares of Con Edison common stock are delivered upon exercise of the options. As equity awards, the fair value of the options is measured at the grant date. There were no options granted in 2012 and 2011.

A summary of changes in the status of stock options awarded as of December 31, 2012 is as follows:


	Con Edison					CECONY
	Shares			Weighted Average Exercise Price		Shares			Weighted Average Exercise Price
Outstanding at 12/31/11		927,025		$	43.046		740,875		$	43.066
Exercised		(318,550	)		43.128		(258,700	)		43.238
Forfeited		(2,000	)		41.665		(1,000	)		43.005
Outstanding at 12/31/12		606,475		$	43.008		481,175		$	42.973

The changes in the fair value of all outstanding options from their grant dates to December 31, 2012 and 2011 (aggregate intrinsic value) for Con Edison were $8 million and $18 million, respectively. The changes in the fair value of all outstanding options from their grant dates to December 31, 2012 and 2011 (aggregate intrinsic value) for CECONY were $6 million and $14 million, respectively. The aggregate intrinsic value of options exercised in 2012 and 2011 were $5 million and $21 million, respectively, and the cash received by Con Edison for payment of the exercise price was $14 million and $88 million, respectively. The weighted average remaining contractual life of options outstanding is two years as of December 31, 2012.

The following table summarizes stock options outstanding at December 31, 2012 for each plan year for the Companies:


			Con Edison				CECONY
Plan Year	Remaining Contractual Life		Options Outstanding/ Exercisable		Weighted Average Exercise Price		Options Outstanding/ Exercisable		Weighted Average Exercise Price
2006		3		228,250	$	43.870		188,150	$	43.841
2005		2		170,125		42.243		139,025		42.258
2004		1		157,000		44.060		112,400		44.072
2003		<1		51,100		38.470		41,600		38.470
Total				606,475	$	43.008		481,175	$	42.973

The income tax benefit Con Edison realized from stock options exercised in the period ended December 31, 2012 was immaterial. The income tax benefit Con Edison realized from stock options exercised in the periods ended December 31, 2011 and 2010 were $2 million and $6 million, respectively.

Restricted Stock Units

Restricted stock unit awards under the LTIP have been made as follows: (i) to officers and certain employees, including awards that provide for adjustment of the number of units (performance-restricted stock units or Performance RSUs); and (ii) in connection with the directors’ deferred compensation plan. Each restricted stock unit awarded represents the right to receive, upon vesting, one share of Con Edison common stock, or, except for units awarded under the directors’ plan, the cash value of a share or a combination thereof.

In accordance with the accounting rules for stock compensation, for outstanding restricted stock awards other than Performance RSUs or awards under the directors’ deferred compensation plan, the Companies have accrued a liability based on the market value of a common share on the grant date and are recognizing compensation expense over the vesting period. The vesting period for awards is three years and is based on the employee’s continuous service to Con Edison. Prior to vesting, the awards are subject to forfeiture in whole or in part under certain circumstances. The awards are “liability awards” because each restricted stock unit represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, prior to vesting, changes in the fair value of the units are reflected in net income. A summary of changes in the status of restricted stock (other than Performance RSUs or awards under the directors’ deferred compensation plan) during the period ended December 31, 2012 is as follows:


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value		Units			Weighted Average Grant Date Fair Value
Non-vested at 12/31/11		65,420		$	45.049		61,920		$	45.049
Granted		22,860			58.420		21,660			58.420
Vested		(21,130	)		39.610		(19,980	)		39.610
Forfeited		(2,010	)		50.452		(1,910	)		50.600
Non-vested at 12/31/12		65,140		$	51.339		61,690		$	51.334

The total expense to be recognized by the Companies in future periods for unvested awards outstanding as of December 31, 2012 for Con Edison was $2 million, including $1 million for CECONY and is expected to be recognized over a weighted average period of one year.

The number of units in each annual Performance RSU award is subject to adjustment as follows: (i) 50 percent of the units awarded will be multiplied by a factor that may range from 0 to 150 percent based on Con Edison’s total shareholder return relative to a specified peer group during a specified performance period (the TSR portion); and (ii) 50 percent of the units awarded will be multiplied by a factor that may range from 0 to 200 percent based on determinations made in connection with CECONY’s Executive Incentive Plan, or, for certain officers, the O&R Annual Team Incentive Plan or goals relating to Con Edison’s competitive energy businesses (the EIP portion). Units generally vest when the performance period ends.

For the TSR portion of Performance RSU, the Companies use a Monte Carlo simulation model to estimate the fair value of the awards. The fair value is recomputed each reporting period as of the earlier of the reporting date and the vesting date. For the EIP portion of Performance RSU, the fair value of the awards is determined using the market price as of the earlier of the reporting date or the vesting date multiplied by the average EIP determination over the vesting period. Performance RSU awards are “liability awards” because each Performance RSU represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, changes in the fair value of the Performance RSUs are reflected in net income. The following table illustrates the assumptions used to calculate the fair value of the awards:


	2012
Risk-free interest rate		0.15% - 3.69%
Expected term		3 years
Expected volatility		15.27%

The risk-free rate is based on the U.S. Treasury zero-coupon yield curve on the date of grant. The expected term of the Performance RSUs is three years, which equals the vesting period. The Companies do not expect significant forfeitures to occur. The expected volatility is calculated using daily closing stock prices over a period of three years, which approximates the expected term of the awards.

A summary of changes in the status of the Performance RSUs TSR portion during the period ended December 31, 2012 is as follows:


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value*		Units			Weighted Average Grant Date Fair Value*
Non-vested at 12/31/11		474,517		$	42.511		387,379		$	42.542
Granted		191,280			49.507		157,348			49.416
Vested		(36,075	)		41.868		(33,653	)		41.869
Forfeited		(10,812	)		45.452		(8,373	)		46.023
Non-vested at 12/31/12		618,910		$	44.659		502,701		$	44.681

*	Fair value is determined using the Monte Carlo simulation described above. Weighted average grant date fair value does not reflect any accrual or payment of dividends prior to vesting.

A summary of changes in the status of the Performance RSUs’ EIP portion during the period ended December 31, 2012 is as follows:


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value*		Units			Weighted Average Grant Date Fair Value*
Non-vested at 12/31/11		474,517		$	46.660		387,379		$	46.599
Granted		191,280			58.852		157,348			58.838
Vested		(36,075	)		39.663		(33,653	)		39.666
Forfeited		(10,812	)		52.247		(8,373	)		53.183
Non-vested at 12/31/12		618,910		$	50.738		502,701		$	50.783

*	Fair value is determined using the market price of one share of Con Edison common stock on the grant date. The market price has not been discounted to reflect that dividends do not accrue and are not payable on Performance RSUs until vesting.

The total expense to be recognized by Con Edison in future periods for unvested Performance RSUs outstanding as of December 31, 2012 is $23 million, including $19 million for CECONY and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY.

Con Edison has a deferred stock compensation plan for non-officer directors. Awards under the deferred compensation stock plan are covered by the LTIP. Each director received 1,785 stock units in 2012 for service as a director. These stock units are deferred until the director’s termination of service. Directors may elect to receive dividend equivalents earned on stock units in cash payments. Restricted stock units issued under the directors’ deferred compensation plan are considered “equity awards,” because they may only be settled in shares. Directors immediately vest in units issued to them. The fair value of the units is determined using the closing price of Con Edison’s common stock on the business day immediately preceding the date of issue. In the period ended December 31, 2012, approximately 30,242 units were issued at a weighted average grant date price of $58.89.

Stock Purchase Plan

The Stock Purchase Plan provides for the Companies to contribute up to $1 for each $9 invested by their directors, officers or employees to purchase Con Edison common stock under the plan. Eligible participants may invest up to $25,000 during any calendar year (subject to an additional limitation for officers and employees of not more than 20% of their pay). Dividends paid on shares held under the plan are reinvested in additional shares unless otherwise directed by the participant.

Participants in the plan immediately vest in shares purchased by them under the plan. The fair value of the shares of Con Edison common stock purchased under the plan was calculated using the average of the high and low composite sale prices at which shares were traded at the New York Stock Exchange on the trading day immediately preceding such purchase dates. During 2012, 2011, and 2010, 665,718, 721,520 and 738,951 shares were purchased under the Stock Purchase Plan at a weighted average price of $59.72, $52.50 and $45.52 per share, respectively.

CECONY [Member]

Stock-Based Compensation

Note M — Stock-Based Compensation


	Con Edison						CECONY
(Millions of Dollars)	2012		2011		2010		2012		2011		2010
Performance-based restricted stock	$	14	$	48	$	27	$	13	$	44	$	25
Restricted stock units		1		3		1		1		3		1
Non-officer director deferred stock compensation		1		1		1		1		1		1
Total	$	16	$	52	$	29	$	15	$	48	$	27
Income Tax Benefit	$	6	$	21	$	12	$	6	$	20	$	11

Stock Options

A summary of changes in the status of stock options awarded as of December 31, 2012 is as follows:


	Con Edison					CECONY
	Shares			Weighted Average Exercise Price		Shares			Weighted Average Exercise Price
Outstanding at 12/31/11		927,025		$	43.046		740,875		$	43.066
Exercised		(318,550	)		43.128		(258,700	)		43.238
Forfeited		(2,000	)		41.665		(1,000	)		43.005
Outstanding at 12/31/12		606,475		$	43.008		481,175		$	42.973

The following table summarizes stock options outstanding at December 31, 2012 for each plan year for the Companies:


			Con Edison				CECONY
Plan Year	Remaining Contractual Life		Options Outstanding/ Exercisable		Weighted Average Exercise Price		Options Outstanding/ Exercisable		Weighted Average Exercise Price
2006		3		228,250	$	43.870		188,150	$	43.841
2005		2		170,125		42.243		139,025		42.258
2004		1		157,000		44.060		112,400		44.072
2003		<1		51,100		38.470		41,600		38.470
Total				606,475	$	43.008		481,175	$	42.973

Restricted Stock Units


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value		Units			Weighted Average Grant Date Fair Value
Non-vested at 12/31/11		65,420		$	45.049		61,920		$	45.049
Granted		22,860			58.420		21,660			58.420
Vested		(21,130	)		39.610		(19,980	)		39.610
Forfeited		(2,010	)		50.452		(1,910	)		50.600
Non-vested at 12/31/12		65,140		$	51.339		61,690		$	51.334


	2012
Risk-free interest rate		0.15% - 3.69%
Expected term		3 years
Expected volatility		15.27%

A summary of changes in the status of the Performance RSUs TSR portion during the period ended December 31, 2012 is as follows:


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value*		Units			Weighted Average Grant Date Fair Value*
Non-vested at 12/31/11		474,517		$	42.511		387,379		$	42.542
Granted		191,280			49.507		157,348			49.416
Vested		(36,075	)		41.868		(33,653	)		41.869
Forfeited		(10,812	)		45.452		(8,373	)		46.023
Non-vested at 12/31/12		618,910		$	44.659		502,701		$	44.681

*	Fair value is determined using the Monte Carlo simulation described above. Weighted average grant date fair value does not reflect any accrual or payment of dividends prior to vesting.

A summary of changes in the status of the Performance RSUs’ EIP portion during the period ended December 31, 2012 is as follows:


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value*		Units			Weighted Average Grant Date Fair Value*
Non-vested at 12/31/11		474,517		$	46.660		387,379		$	46.599
Granted		191,280			58.852		157,348			58.838
Vested		(36,075	)		39.663		(33,653	)		39.666
Forfeited		(10,812	)		52.247		(8,373	)		53.183
Non-vested at 12/31/12		618,910		$	50.738		502,701		$	50.783

*	Fair value is determined using the market price of one share of Con Edison common stock on the grant date. The market price has not been discounted to reflect that dividends do not accrue and are not payable on Performance RSUs until vesting.

Stock Purchase Plan

The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details.

Financial Information by Business Segment

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+ Details

Financial Information by Business Segment

12 Months Ended

Dec. 31, 2012

Note N — Financial Information by Business Segment

The business segments of each of the Companies, which are its operating segments, were determined based on management’s reporting and decision-making requirements in accordance with the accounting rules for segment reporting.

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.

All revenues of these business segments, excluding revenues earned by Con Edison Development on certain energy infrastructure projects, which are deemed to be immaterial, are from customers located in the United States of America. Also, all assets of the business segments, excluding certain investments in energy infrastructure projects by Con Edison Development ($228 million at December 31, 2012), are located in the United States of America. The accounting policies of the segments are the same as those described in Note A.

Common services shared by the business segments are assigned directly or allocated based on various cost factors, depending on the nature of the service provided.

The financial data for the business segments are as follows:


As of and for the Year Ended December 31, 2012 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,176		$	15		$	710	$	1,693		$	423		$	393	$	28,339	$	1,375
Gas		1,415			5			120		346			82			99		5,925		426
Steam		596			77			64		54			40			22		2,621		108
Consolidation adjustments		-			(97	)		-		-			-			-		-		-
Total CECONY	$	10,187		$	-		$	894	$	2,093		$	545		$	514	$	36,885	$	1,909
O&R
Electric	$	592		$	-		$	38	$	83		$	19		$	17	$	1,960	$	98
Gas		203			-			15		40			10			11		706		39
Other*		-			-			-		-			2			-		5		-
Total O&R	$	795		$	-		$	53	$	123		$	31		$	28	$	2,671	$	137
Competitive energy businesses	$	1,213		$	8		$	8	$	125		$	1		$	52	$	1,061	$	492
Other**		(7	)		(8	)		-		(2	)		27			-		592		-
Total Con Edison	$	12,188		$	-		$	955	$	2,339		$	604		$	594	$	41,209	$	2,538
As of and for the Year Ended December 31, 2011 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,228		$	12		$	656	$	1,695		$	414		$	481	$	27,123	$	1,354
Gas		1,521			5			110		295			78			43		5,518		335
Steam		683			79			63		93			42			43		2,577		89
Consolidation adjustments		-			(96	)		-		-			-			-		-		-
Total CECONY	$	10,432		$	-		$	829	$	2,083		$	534		$	567	$	35,218	$	1,778
O&R
Electric	$	641		$	-		$	35	$	81		$	20		$	21	$	1,755	$	79
Gas		214			-			13		33			12			9		722		32
Other*		-			-			-		-			2			-		8		-
Total O&R	$	855		$	-		$	48	$	114		$	34		$	30	$	2,485	$	111
Competitive energy businesses	$	1,617		$	13		$	7	$	46		$	(1	)	$	20	$	856	$	114
Other**		(18	)		(13	)		-		(4	)		27			-		655		-
Total Con Edison	$	12,886		$	-		$	884	$	2,239		$	594		$	617	$	39,214	$	2,003
As of and for the Year Ended December 31, 2010 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,376		$	12		$	623	$	1,549		$	424		$	371	$	25,045	$	1,421
Gas		1,541			5			102		310			82			91		5,095		334
Steam		656			74			62		63			43			29		2,465		111
Consolidation adjustments		-			(91	)		-		-			-			-		-		-
Total CECONY	$	10,573		$	-		$	787	$	1,922		$	549		$	491	$	32,605	$	1,866
O&R
Electric	$	692		$	-		$	32	$	74		$	22		$	18	$	1,630	$	99
Gas		218			-			12		34			12			8		686		36
Other*		-			-			-		-			1			-		32		-
Total O&R	$	910		$	-		$	44	$	108		$	35		$	26	$	2,348	$	135
Competitive energy businesses	$	1,883		$	9		$	9	$	97		$	(3	)	$	37	$	828	$	28
Other**		(41	)		(9	)		-		(7	)		28			-		567		-
Total Con Edison	$	13,325		$	-		$	840	$	2,120		$	609		$	554	$	36,348	$	2,029

*	Includes amounts related to the RECO securitization.

**	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 and $4 million in deposits relating to the PPA and interconnection agreements. The total cost to acquire and construct these projects was $340 million. Alpaugh commenced commercial operation in December 2012.

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 N — Financial Information by Business Segment

Common services shared by the business segments are assigned directly or allocated based on various cost factors, depending on the nature of the service provided.

The financial data for the business segments are as follows:


As of and for the Year Ended December 31, 2012 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,176		$	15		$	710	$	1,693		$	423		$	393	$	28,339	$	1,375
Gas		1,415			5			120		346			82			99		5,925		426
Steam		596			77			64		54			40			22		2,621		108
Consolidation adjustments		-			(97	)		-		-			-			-		-		-
Total CECONY	$	10,187		$	-		$	894	$	2,093		$	545		$	514	$	36,885	$	1,909
O&R
Electric	$	592		$	-		$	38	$	83		$	19		$	17	$	1,960	$	98
Gas		203			-			15		40			10			11		706		39
Other*		-			-			-		-			2			-		5		-
Total O&R	$	795		$	-		$	53	$	123		$	31		$	28	$	2,671	$	137
Competitive energy businesses	$	1,213		$	8		$	8	$	125		$	1		$	52	$	1,061	$	492
Other**		(7	)		(8	)		-		(2	)		27			-		592		-
Total Con Edison	$	12,188		$	-		$	955	$	2,339		$	604		$	594	$	41,209	$	2,538
As of and for the Year Ended December 31, 2011 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,228		$	12		$	656	$	1,695		$	414		$	481	$	27,123	$	1,354
Gas		1,521			5			110		295			78			43		5,518		335
Steam		683			79			63		93			42			43		2,577		89
Consolidation adjustments		-			(96	)		-		-			-			-		-		-
Total CECONY	$	10,432		$	-		$	829	$	2,083		$	534		$	567	$	35,218	$	1,778
O&R
Electric	$	641		$	-		$	35	$	81		$	20		$	21	$	1,755	$	79
Gas		214			-			13		33			12			9		722		32
Other*		-			-			-		-			2			-		8		-
Total O&R	$	855		$	-		$	48	$	114		$	34		$	30	$	2,485	$	111
Competitive energy businesses	$	1,617		$	13		$	7	$	46		$	(1	)	$	20	$	856	$	114
Other**		(18	)		(13	)		-		(4	)		27			-		655		-
Total Con Edison	$	12,886		$	-		$	884	$	2,239		$	594		$	617	$	39,214	$	2,003
As of and for the Year Ended December 31, 2010 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,376		$	12		$	623	$	1,549		$	424		$	371	$	25,045	$	1,421
Gas		1,541			5			102		310			82			91		5,095		334
Steam		656			74			62		63			43			29		2,465		111
Consolidation adjustments		-			(91	)		-		-			-			-		-		-
Total CECONY	$	10,573		$	-		$	787	$	1,922		$	549		$	491	$	32,605	$	1,866
O&R
Electric	$	692		$	-		$	32	$	74		$	22		$	18	$	1,630	$	99
Gas		218			-			12		34			12			8		686		36
Other*		-			-			-		-			1			-		32		-
Total O&R	$	910		$	-		$	44	$	108		$	35		$	26	$	2,348	$	135
Competitive energy businesses	$	1,883		$	9		$	9	$	97		$	(3	)	$	37	$	828	$	28
Other**		(41	)		(9	)		-		(7	)		28			-		567		-
Total Con Edison	$	13,325		$	-		$	840	$	2,120		$	609		$	554	$	36,348	$	2,029

*	Includes amounts related to the RECO securitization.

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

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

Derivative Instruments and Hedging Activities

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+ Details

Derivative Instruments and Hedging Activities

12 Months Ended

Dec. 31, 2012

Note O — Derivative Instruments and Hedging Activities

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

Energy Price Hedging

Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, and steam by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. The fair values of these hedges at December 31, 2012 and 2011 were as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Fair value of net derivative assets/(liabilities) – gross	$	(90)	$	(249)	$	(56)	$	(144)
Impact of netting of cash collateral		84		110		47		46
Fair value of net derivative assets/(liabilities) – net	$	(6)	$	(139)	$	(9)	$	(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 December 31, 2012, Con Edison and CECONY had $113 million and $19 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $41 million with investment-grade counterparties, $41 million with commodity exchange brokers, $28 million with independent system operators and $3 million with non-investment grade/non-rated counterparties. CECONY’s net credit exposure consisted of $1 million with investment-grade counterparties and $18 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 December 31, 2012 were:


	Fair Value of Commodity Derivatives(a)
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
	Derivative Assets
Current	Other current assets	$	64		$	18
Long-term	Other deferred charges and noncurrent assets		22			9
Total derivative assets		$	86		$	27
Impact of netting			(20	)		3
Net derivative assets		$	66		$	30
	Derivative Liabilities
Current	Fair value of derivative liabilities	$	122		$	58
Long-term	Fair value of derivative liabilities		54			25
Total derivative liabilities		$	176		$	83
Impact of netting			(104	)		(44	)
Net derivative liabilities		$	72		$	39

(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:


	Fair Value of Commodity Derivatives(a)
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
	Derivative Assets
Current	Other current assets	$	139		$	16
Long-term	Other deferred charges and noncurrent 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. See “Recoverable Energy Costs” in Note A. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements. Con Edison’s competitive energy businesses record realized and unrealized gains and losses on their derivative contracts in earnings in the reporting period in which they occur.

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


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Year Ended December 31, 2012
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(1	)	$	(1	)
Long-term	Regulatory liabilities		-			-
Total deferred gains/(losses)		$	(1	)	$	(1	)
Current	Deferred derivative losses	$	95		$	80
Current	Recoverable energy costs		(220	)		(192	)
Long-term	Deferred derivative losses		17			24
Total deferred gains/(losses)		$	(108	)	$	(88	)
Net deferred gains/(losses)		$	(109	)	$	(89	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(54	)(b)	$	-
	Gas purchased for resale		(5	)		-
	Non-utility revenue		(11	)(b)		-
Total pre-tax gain/(loss) recognized in income		$	(70	)	$	-

(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 year ended December 31, 2012, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(14) million and $82 million, respectively.

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


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Year Ended December 31, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(3	)	$	(2	)
Long-term	Regulatory liabilities		(1	)		(1	)
Total deferred gains/(losses)		$	(4	)	$	(3	)
Current	Deferred derivative losses	$	26		$	11
Current	Recoverable energy costs		(247	)		(185	)
Long-term	Deferred derivative losses		11			4
Total deferred gains/(losses)		$	(210	)	$	(170	)
Net deferred gains/(losses)		$	(214	)	$	(173	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(78	)(b)	$	-
	Gas purchased for resale		(18	)		-
	Non-utility revenue		(30	)(b)		-
Total pre-tax gain/(loss) recognized in income		$	(126	)	$	-

(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 year ended December 31, 2011, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(34) million and $11 million, respectively.

As of December 31, 2012, Con Edison had 1,147 contracts, including 581 CECONY contracts, which were considered to be derivatives under the accounting rules for derivatives and hedging (excluding qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts). The following table presents the number of contracts by commodity type:


	Electric Derivatives								Gas Derivatives
	Number of Energy Contracts(a)		MWHs(b)		Number of Capacity Contracts(a)		MWs(b)		Number of Contracts(a)		Dths(b)		Total Number Of Contracts(a)
Con Edison		496		15,761,464		59		11,668		592		84,706,809		1,147
CECONY		97		3,565,325		-		-		484		79,460,000		581

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

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

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

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

The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a net liability position and collateral posted at December 31, 2012, and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade were:


(Millions of Dollars)	Con Edison(a)			CECONY(a)
Aggregate fair value – net liabilities	$	52		$	39
Collateral posted	$	-		$	-
Additional collateral^(b) (downgrade one level from current ratings)	$	4		$	4
Additional collateral^(b) (downgrade to below investment grade from current ratings)	$	77	(c)	$	43	(c)

(a)

Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and 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 December 31, 2012, would have amounted to an estimated $24 million for Con Edison, including $10 million for CECONY. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

(b)

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

(c)	Derivative instruments that are net assets have been excluded from the table. At December 31, 2012, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $24 million, including $1 million for CECONY.

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 December 31, 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 year ended December 31, 2012 was $2 million. 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 O — Derivative Instruments and Hedging Activities

Energy Price Hedging


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Fair value of net derivative assets/(liabilities) – gross	$	(90)	$	(249)	$	(56)	$	(144)
Impact of netting of cash collateral		84		110		47		46
Fair value of net derivative assets/(liabilities) – net	$	(6)	$	(139)	$	(9)	$	(98)

Credit Exposure

Economic Hedges

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


	Fair Value of Commodity Derivatives(a)
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
	Derivative Assets
Current	Other current assets	$	64		$	18
Long-term	Other deferred charges and noncurrent assets		22			9
Total derivative assets		$	86		$	27
Impact of netting			(20	)		3
Net derivative assets		$	66		$	30
	Derivative Liabilities
Current	Fair value of derivative liabilities	$	122		$	58
Long-term	Fair value of derivative liabilities		54			25
Total derivative liabilities		$	176		$	83
Impact of netting			(104	)		(44	)
Net derivative liabilities		$	72		$	39

(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:


	Fair Value of Commodity Derivatives(a)
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
	Derivative Assets
Current	Other current assets	$	139		$	16
Long-term	Other deferred charges and noncurrent 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 following table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the year ended December 31, 2012:


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Year Ended December 31, 2012
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(1	)	$	(1	)
Long-term	Regulatory liabilities		-			-
Total deferred gains/(losses)		$	(1	)	$	(1	)
Current	Deferred derivative losses	$	95		$	80
Current	Recoverable energy costs		(220	)		(192	)
Long-term	Deferred derivative losses		17			24
Total deferred gains/(losses)		$	(108	)	$	(88	)
Net deferred gains/(losses)		$	(109	)	$	(89	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(54	)(b)	$	-
	Gas purchased for resale		(5	)		-
	Non-utility revenue		(11	)(b)		-
Total pre-tax gain/(loss) recognized in income		$	(70	)	$	-

(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 year ended December 31, 2012, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(14) million and $82 million, respectively.

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


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Year Ended December 31, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(3	)	$	(2	)
Long-term	Regulatory liabilities		(1	)		(1	)
Total deferred gains/(losses)		$	(4	)	$	(3	)
Current	Deferred derivative losses	$	26		$	11
Current	Recoverable energy costs		(247	)		(185	)
Long-term	Deferred derivative losses		11			4
Total deferred gains/(losses)		$	(210	)	$	(170	)
Net deferred gains/(losses)		$	(214	)	$	(173	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(78	)(b)	$	-
	Gas purchased for resale		(18	)		-
	Non-utility revenue		(30	)(b)		-
Total pre-tax gain/(loss) recognized in income		$	(126	)	$	-

(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 year ended December 31, 2011, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(34) million and $11 million, respectively.


	Electric Derivatives								Gas Derivatives
	Number of Energy Contracts(a)		MWHs(b)		Number of Capacity Contracts(a)		MWs(b)		Number of Contracts(a)		Dths(b)		Total Number Of Contracts(a)
Con Edison		496		15,761,464		59		11,668		592		84,706,809		1,147
CECONY		97		3,565,325		-		-		484		79,460,000		581

(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.


(Millions of Dollars)	Con Edison(a)			CECONY(a)
Aggregate fair value – net liabilities	$	52		$	39
Collateral posted	$	-		$	-
Additional collateral^(b) (downgrade one level from current ratings)	$	4		$	4
Additional collateral^(b) (downgrade to below investment grade from current ratings)	$	77	(c)	$	43	(c)

(a)

(b)

(c)	Derivative instruments that are net assets have been excluded from the table. At December 31, 2012, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $24 million, including $1 million for CECONY.

Interest Rate Swap

The entire disclosure for the entity's entire derivative instruments and hedging activities. Describes an entity's risk management strategies, derivatives in hedging activities and non-hedging derivative instruments, the assets, obligations, liabilities, revenues and expenses arising therefrom, and the amounts of and methodologies and assumptions used in determining the amounts of such items.

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+ Details

Fair Value Measurements

12 Months Ended

Dec. 31, 2012

Fair Value Measurements

Note P — 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 December 31, 2012 are summarized below.


	Level 1					Level 2						Level 3						Netting Adjustments(4)						Total
(Millions of Dollars)	Con Edison			CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity	$	-		$	-	$	43		$	8		$	33		$	10		$	(10	)	$	12		$	66		$	30
Transfer in(5)(6)		-			-		-			-			-			-			-			-			-			-
Transfer out(5)(6)		-			-		-			-			-			-			-			-			-			-
Commodity Total(1)	$	-		$	-	$	43		$	8		$	33		$	10		$	(10	)	$	12		$	66		$	30
Other assets	$	106		$	99	$	2		$	3		$	105		$	95		$	-		$	-		$	213		$	197
Transfer in(5)(6)		-			-		105			95			-			-			-			-			105			95
Transfer out(5)(6)		-			-		-			-			(105	)		(95	)		-			-			(105	)		(95	)
Other assets(3)	$	106		$	99	$	107		$	98		$	-		$	-		$	-		$	-		$	213		$	197
Total	$	106		$	99	$	150		$	106		$	33		$	10		$	(10	)	$	12		$	279		$	227
Derivative liabilities:
Commodity	$	5		$	3	$	114		$	62		$	47		$	9		$	(94	)	$	(35	)	$	72		$	39
Transfer in(5)(6)		9			9		13			9			2			-			-			-			24			18
Transfer out(5)(6)		(2	)		-		(11	)		(9	)		(11	)		(9	)		-			-			(24	)		(18	)
Commodity Total(1)	$	12		$	12	$	116		$	62		$	38		$	-		$	(94	)	$	(35	)	$	72		$	39
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	$	12		$	12	$	122		$	62		$	38		$	-		$	(94	)	$	(35	)	$	78		$	39

(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 O.

(2)	See Note O.

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

(2)	See Note O.

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

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

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

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

(7)	Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 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 December 31, 2012 (Millions of Dollars)			Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$	(5	)	Discounted Cash Flow	Forward prices(1)	$28-$82 per MWH
Electricity Wholesale Contract		(1	)	Discounted Cash Flow	Forward prices(2) New Jersey solar renewable energy credit (SREC)(2)	$29-$48 per MWH $90 per SREC
Standard Offer Capacity Agreements		(12	)	Discounted Cash Flow	Forward capacity prices(1) Forward price escalator(1) Present value factor(1)	$166 MW - day 0% - 3% 1.66%
Transmission Congestion Contracts / Financial Transmission Rights		13		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) Forward energy prices and zonal losses(1)	17.5% - 38% 8.5% - 31% $0.01 - $12
Total Con Edison —Commodity	$	(5	)
CECONY — Commodity
Transmission Congestion Contracts	$	10		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% 8.5%-31%

(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 years ended December 31, 2012 and 2011 and classified as Level 3 in the fair value hierarchy:


	For the Year Ended December 31, 2012
				Total Gains/(Losses) – Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2012			Included in Earnings			Included in Regulatory Assets and Liabilities		Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of December 31, 2012
Con Edison
Derivatives:
Commodity	$	(62	)	$	(112	)	$	16	$	22	$	-	$	-	$	122	$	9		$	(5	)
Interest rate contract		(8	)		(1	)		-		-		-		-		1		8	(2)		-
Other assets(1)		99			3			3		-		-		-		-		(105	)(2)		-
Total	$	29		$	(110	)	$	19	$	22	$	-	$	-	$	123	$	(88	)	$	(5	)
CECONY
Derivatives:
Commodity	$	(7	)	$	(32	)	$	8	$	18	$	-	$	-	$	14	$	9		$	10
Other assets(1)		90			3			2		-		-		-		-		(95	)(2)		-
Total	$	83		$	(29	)	$	10	$	18	$	-	$	-	$	14	$	(86	)	$	10

(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.


	For the Year Ended December 31, 2011
				Total Gains/(Losses) – Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of December 31, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	(113	)	$	20		$	32	$	-	$	-	$	67	$	20	$	(62	)
Interest rate contract		(10	)		(3	)		2			-		-		-		3		-		(8	)
Other assets(1)		101			-			(2	)		-		-		-		-		-		99
Total	$	3		$	(116	)	$	20		$	32	$	-	$	-	$	70	$	20	$	29
CECONY
Derivatives:
Commodity	$	(26	)	$	(21	)	$	-		$	19	$	-	$	-	$	2	$	19	$	(7	)
Other assets(1)		92			-			(2	)		-		-		-		-		-		90
Total	$	66		$	(21	)	$	(2	)	$	19	$	-	$	-	$	2	$	19	$	83

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

For the Utilities, realized gains and losses on Level 3 commodity derivative assets and liabilities are reported as part of purchased power, gas and fuel costs. The Utilities generally recover these costs in accordance with rate provisions approved by the applicable state public utilities commissions. See Note A. 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 ($12 million loss and $33 million loss) and purchased power costs ($46 million loss and $29 million loss) on the consolidated income statement for the years ended December 31, 2012 and 2011, respectively. The change in fair value relating to Level 3 commodity derivative assets held at December 31, 2012 and 2011 is included in non-utility revenues ($12 million loss and $33 million loss), and purchased power costs ($46 million gain and $15 million gain) on the consolidated income statement for the years ended December 31, 2012 and 2011, respectively.

The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2012, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. To assess nonperformance risk, the Companies considered information such as collateral requirements, master netting arrangements, letters of credit and parent company guarantees, and applied a market-based method by using the counterparty (for an asset) or the Companies’ (for a liability) credit default swaps rates.

CECONY [Member]

Fair Value Measurements

Note P — Fair Value Measurements

•

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


	Level 1					Level 2						Level 3						Netting Adjustments(4)						Total
(Millions of Dollars)	Con Edison			CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity	$	-		$	-	$	43		$	8		$	33		$	10		$	(10	)	$	12		$	66		$	30
Transfer in(5)(6)		-			-		-			-			-			-			-			-			-			-
Transfer out(5)(6)		-			-		-			-			-			-			-			-			-			-
Commodity Total(1)	$	-		$	-	$	43		$	8		$	33		$	10		$	(10	)	$	12		$	66		$	30
Other assets	$	106		$	99	$	2		$	3		$	105		$	95		$	-		$	-		$	213		$	197
Transfer in(5)(6)		-			-		105			95			-			-			-			-			105			95
Transfer out(5)(6)		-			-		-			-			(105	)		(95	)		-			-			(105	)		(95	)
Other assets(3)	$	106		$	99	$	107		$	98		$	-		$	-		$	-		$	-		$	213		$	197
Total	$	106		$	99	$	150		$	106		$	33		$	10		$	(10	)	$	12		$	279		$	227
Derivative liabilities:
Commodity	$	5		$	3	$	114		$	62		$	47		$	9		$	(94	)	$	(35	)	$	72		$	39
Transfer in(5)(6)		9			9		13			9			2			-			-			-			24			18
Transfer out(5)(6)		(2	)		-		(11	)		(9	)		(11	)		(9	)		-			-			(24	)		(18	)
Commodity Total(1)	$	12		$	12	$	116		$	62		$	38		$	-		$	(94	)	$	(35	)	$	72		$	39
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	$	12		$	12	$	122		$	62		$	38		$	-		$	(94	)	$	(35	)	$	78		$	39

(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 O.

(2)	See Note O.

(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)

(2)	See Note O.

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

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

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

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

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


	Fair Value of Level 3 at December 31, 2012 (Millions of Dollars)			Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$	(5	)	Discounted Cash Flow	Forward prices(1)	$28-$82 per MWH
Electricity Wholesale Contract		(1	)	Discounted Cash Flow	Forward prices(2) New Jersey solar renewable energy credit (SREC)(2)	$29-$48 per MWH $90 per SREC
Standard Offer Capacity Agreements		(12	)	Discounted Cash Flow	Forward capacity prices(1) Forward price escalator(1) Present value factor(1)	$166 MW - day 0% - 3% 1.66%
Transmission Congestion Contracts / Financial Transmission Rights		13		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) Forward energy prices and zonal losses(1)	17.5% - 38% 8.5% - 31% $0.01 - $12
Total Con Edison —Commodity	$	(5	)
CECONY — Commodity
Transmission Congestion Contracts	$	10		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% 8.5%-31%

(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.


	For the Year Ended December 31, 2012
				Total Gains/(Losses) – Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2012			Included in Earnings			Included in Regulatory Assets and Liabilities		Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of December 31, 2012
Con Edison
Derivatives:
Commodity	$	(62	)	$	(112	)	$	16	$	22	$	-	$	-	$	122	$	9		$	(5	)
Interest rate contract		(8	)		(1	)		-		-		-		-		1		8	(2)		-
Other assets(1)		99			3			3		-		-		-		-		(105	)(2)		-
Total	$	29		$	(110	)	$	19	$	22	$	-	$	-	$	123	$	(88	)	$	(5	)
CECONY
Derivatives:
Commodity	$	(7	)	$	(32	)	$	8	$	18	$	-	$	-	$	14	$	9		$	10
Other assets(1)		90			3			2		-		-		-		-		(95	)(2)		-
Total	$	83		$	(29	)	$	10	$	18	$	-	$	-	$	14	$	(86	)	$	10

(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.


	For the Year Ended December 31, 2011
				Total Gains/(Losses) – Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of December 31, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	(113	)	$	20		$	32	$	-	$	-	$	67	$	20	$	(62	)
Interest rate contract		(10	)		(3	)		2			-		-		-		3		-		(8	)
Other assets(1)		101			-			(2	)		-		-		-		-		-		99
Total	$	3		$	(116	)	$	20		$	32	$	-	$	-	$	70	$	20	$	29
CECONY
Derivatives:
Commodity	$	(26	)	$	(21	)	$	-		$	19	$	-	$	-	$	2	$	19	$	(7	)
Other assets(1)		92			-			(2	)		-		-		-		-		-		90
Total	$	66		$	(21	)	$	(2	)	$	19	$	-	$	-	$	2	$	19	$	83

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

The entire disclosure of the fair value measurement of assets and liabilities, which includes financial instruments measured at fair value that are classified in shareholders' equity, which may be measured on a recurring or nonrecurring basis.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 157

-Paragraph 33

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 157

-Paragraph 32

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 107

-Paragraph 10

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 820

-SubTopic 10

-Section 50

-Paragraph 3

-URI http://asc.fasb.org/extlink&oid=7578670&loc=d3e19279-110258

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 820

-SubTopic 10

-Section 50

-Paragraph 1

-URI http://asc.fasb.org/extlink&oid=7578670&loc=d3e19190-110258

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 820

-SubTopic 10

-Section 50

-Paragraph 2

-URI http://asc.fasb.org/extlink&oid=7578670&loc=d3e19207-110258

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 157

-Paragraph 6

-Footnote 4

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Variable Interest Entities	12 Months Ended
Variable Interest Entities	Dec. 31, 2012
Variable Interest Entities	Note Q – Variable Interest Entities The Companies have not identified any interests they have in any variable interest entity (VIE) that would require the Companies to include the financial position and results of operations of the VIE in the Companies’ consolidated financial statements. The accounting rules for consolidation address the consolidation of a VIE by a business enterprise that is the primary beneficiary. A VIE is an entity that does not have a sufficient equity investment at risk to permit it to finance its activities without additional subordinated financial support, or whose equity investors lack the characteristics of a controlling financial interest. The primary beneficiary is the business enterprise that has the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and either absorbs a significant amount of the VIE’s losses or has the right to receive benefits that could be significant to the VIE. Con Edison enters into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, Con Edison retains or may retain a variable interest in these entities. CECONY has a variable interest in a non-consolidated VIE, Astoria Energy, LLC (Astoria Energy), with which CECONY has entered into a long-term electricity purchase agreement. CECONY is not the primary beneficiary of this VIE since CECONY does not have the power to direct the activities that CECONY believes most significantly impact the economic performance of Astoria Energy. In particular, CECONY has not invested in, or guaranteed the indebtedness of, Astoria Energy and CECONY does not operate or maintain Astoria Energy’s generating facilities. CECONY also has long-term electricity purchase agreements with the following five potential VIEs: Sithe/Independence Power Partners, LP, Cogen Technologies Linden Venture, LP, Selkirk Cogen Partners, LP, Brooklyn Navy Yard Cogeneration Partners, LP, and Indeck Energy Services of Corinth, Inc. In 2012, requests were made of these five counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY’s maximum exposure to loss with respect to Astoria Energy and the five potential VIEs. Con Edison has a variable interest in a non-consolidated VIE, Pilesgrove Solar, LLC (Pilesgrove), in which Con Edison Development, starting in 2010, participated with a third party to develop, construct, and operate a photovoltaic solar energy generation project. The project was constructed for approximately $90 million and commenced commercial operation in August 2011. Con Edison is not the primary beneficiary of this VIE since the power to direct the activities that most significantly impact the economics of Pilesgrove is shared equally between Con Edison Development and the third party. Included in the Con Edison’s consolidated balance sheet at December 31, 2012 is $24 million in assets related to Pilesgrove which represents Con Edison Development’s investment including earnings in Pilesgrove and is the current maximum exposure to loss in Pilesgrove.
CECONY [Member]
Variable Interest Entities	Note Q – Variable Interest Entities The Companies have not identified any interests they have in any variable interest entity (VIE) that would require the Companies to include the financial position and results of operations of the VIE in the Companies’ consolidated financial statements. The accounting rules for consolidation address the consolidation of a VIE by a business enterprise that is the primary beneficiary. A VIE is an entity that does not have a sufficient equity investment at risk to permit it to finance its activities without additional subordinated financial support, or whose equity investors lack the characteristics of a controlling financial interest. The primary beneficiary is the business enterprise that has the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and either absorbs a significant amount of the VIE’s losses or has the right to receive benefits that could be significant to the VIE. Con Edison enters into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, Con Edison retains or may retain a variable interest in these entities. CECONY has a variable interest in a non-consolidated VIE, Astoria Energy, LLC (Astoria Energy), with which CECONY has entered into a long-term electricity purchase agreement. CECONY is not the primary beneficiary of this VIE since CECONY does not have the power to direct the activities that CECONY believes most significantly impact the economic performance of Astoria Energy. In particular, CECONY has not invested in, or guaranteed the indebtedness of, Astoria Energy and CECONY does not operate or maintain Astoria Energy’s generating facilities. CECONY also has long-term electricity purchase agreements with the following five potential VIEs: Sithe/Independence Power Partners, LP, Cogen Technologies Linden Venture, LP, Selkirk Cogen Partners, LP, Brooklyn Navy Yard Cogeneration Partners, LP, and Indeck Energy Services of Corinth, Inc. In 2012, requests were made of these five counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY’s maximum exposure to loss with respect to Astoria Energy and the five potential VIEs. Con Edison has a variable interest in a non-consolidated VIE, Pilesgrove Solar, LLC (Pilesgrove), in which Con Edison Development, starting in 2010, participated with a third party to develop, construct, and operate a photovoltaic solar energy generation project. The project was constructed for approximately $90 million and commenced commercial operation in August 2011. Con Edison is not the primary beneficiary of this VIE since the power to direct the activities that most significantly impact the economics of Pilesgrove is shared equally between Con Edison Development and the third party. Included in the Con Edison’s consolidated balance sheet at December 31, 2012 is $24 million in assets related to Pilesgrove which represents Con Edison Development’s investment including earnings in Pilesgrove and is the current maximum exposure to loss in Pilesgrove.

Asset Retirement Obligations	12 Months Ended
Asset Retirement Obligations	Dec. 31, 2012
Asset Retirement Obligations	Note R – Asset Retirement Obligations Con Edison and CECONY account for retirement obligations on their assets in accordance with the accounting rules for asset retirement obligations. This accounting standard requires recognition of a liability for legal obligations associated with the retirement of long-lived assets. When the liability is initially recorded, asset retirement costs are capitalized by increasing the carrying amount of the related asset. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. Such accretion and depreciation expense, pursuant to accounting rules for regulated operations, is applied against the Companies’ regulatory liabilities. The Utilities include in depreciation expense the estimated removal costs, less salvage, for utility plant assets. In accordance with the accounting rules for asset retirement obligations, future removal costs that do not represent legal asset retirement obligations are recorded as regulatory liabilities pursuant to the accounting rules for regulated operations. The related regulatory liabilities recorded for Con Edison and CECONY were $503 million and $420 million at December 31, 2012 and $448 million and $372 million at December 31, 2011, respectively. The Companies identified future asset retirement obligations associated with the removal of asbestos and asbestos-containing material in their buildings and equipment within the generating stations and substations, and within the steam and gas distribution systems. The Companies also identified asset retirement obligations relating to gas pipelines abandoned in place. The estimates of future liabilities were developed using historical information, and where available, quoted prices from outside contractors. The obligation for the cost of asbestos removal from the Companies’ generating stations and substation structures was not accrued since the retirement dates cannot be reasonably estimated. At December 31, 2012, the liabilities of Con Edison and CECONY for the fair value of their legal asset retirement obligations were $158 million, as compared with $145 million at December 31, 2011. The increase in liabilities at December 31, 2012 was due to changes in estimated cash flows ($24 million) and accretion expense ($6 million), offset in part by liabilities settled ($17 million). Con Edison and CECONY also recorded a reduction of $13 million and $7 million at December 31, 2012 and 2011, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.
CECONY [Member]
Asset Retirement Obligations	Note R – Asset Retirement Obligations Con Edison and CECONY account for retirement obligations on their assets in accordance with the accounting rules for asset retirement obligations. This accounting standard requires recognition of a liability for legal obligations associated with the retirement of long-lived assets. When the liability is initially recorded, asset retirement costs are capitalized by increasing the carrying amount of the related asset. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. Such accretion and depreciation expense, pursuant to accounting rules for regulated operations, is applied against the Companies’ regulatory liabilities. The Utilities include in depreciation expense the estimated removal costs, less salvage, for utility plant assets. In accordance with the accounting rules for asset retirement obligations, future removal costs that do not represent legal asset retirement obligations are recorded as regulatory liabilities pursuant to the accounting rules for regulated operations. The related regulatory liabilities recorded for Con Edison and CECONY were $503 million and $420 million at December 31, 2012 and $448 million and $372 million at December 31, 2011, respectively. The Companies identified future asset retirement obligations associated with the removal of asbestos and asbestos-containing material in their buildings and equipment within the generating stations and substations, and within the steam and gas distribution systems. The Companies also identified asset retirement obligations relating to gas pipelines abandoned in place. The estimates of future liabilities were developed using historical information, and where available, quoted prices from outside contractors. The obligation for the cost of asbestos removal from the Companies’ generating stations and substation structures was not accrued since the retirement dates cannot be reasonably estimated. At December 31, 2012, the liabilities of Con Edison and CECONY for the fair value of their legal asset retirement obligations were $158 million, as compared with $145 million at December 31, 2011. The increase in liabilities at December 31, 2012 was due to changes in estimated cash flows ($24 million) and accretion expense ($6 million), offset in part by liabilities settled ($17 million). Con Edison and CECONY also recorded a reduction of $13 million and $7 million at December 31, 2012 and 2011, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.

Related Party Transactions

The entire disclosure for an asset retirement obligation and the associated long-lived asset. An asset retirement obligation is a legal obligation associated with the disposal or retirement from service of a tangible long-lived asset that results from the acquisition, construction or development, or the normal operations of a long-lived asset, except for certain obligations of lessees.

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Related Party Transactions

12 Months Ended

Dec. 31, 2012

Note S – Related Party Transactions

The Utilities and Con Edison’s competitive businesses provide administrative and other services to each other pursuant to cost allocation procedures approved by the NYSPSC. The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2012, 2011, and 2010 were as follows:


	CECONY
(Millions of Dollars)	2012		2011		2010
Cost of services provided	$	83	$	79	$	74
Cost of services received	$	49	$	48	$	45

In addition, CECONY and O&R have joint gas supply arrangements, in connection with which CECONY sold to O&R $54 million, $81 million and $99 million of natural gas for the years ended December 31, 2012, 2011, and 2010, respectively. These amounts are net of the effect of related hedging transactions.

FERC has authorized CECONY through 2013 to lend funds to O&R from time to time, for periods of not more than 12 months, in amounts not to exceed $250 million outstanding at any time, at prevailing market rates. There were no outstanding loans to O&R at December 31, 2012 and 2011.

CECONY [Member]

Related Party Transactions

Note S – Related Party Transactions


	CECONY
(Millions of Dollars)	2012		2011		2010
Cost of services provided	$	83	$	79	$	74
Cost of services received	$	49	$	48	$	45

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

Schedule I - Condensed Financial Information

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Schedule I - Condensed Financial Information

12 Months Ended

Dec. 31, 2012

Schedule I

Condensed Financial Information of Consolidated Edison, Inc.*

Condensed Income Statement

(Parent Company Only)


(Millions of Dollars, except per share amounts)	2012			2011			2010
Equity in earnings of subsidiaries	$	1,154		$	1,064		$	1,008
Other income (deductions), net of taxes		12			15			12
Interest expense		(28	)		(28	)		(28	)
Net Income for Common Stock	$	1,138		$	1,051		$	992
Comprehensive Income for Common Stock	$	1,138		$	1,051		$	992
Net Income Per Common Share – Basic	$	3.88		$	3.59		$	3.49
Net Income Per Common Share – Diluted	$	3.86		$	3.57		$	3.47
Dividends Declared Per Share Of Common Stock	$	2.42		$	2.40		$	2.38
Average Number Of Shares Outstanding – Basic (In Millions)		292.9			292.6			284.3
Average Number Of Shares Outstanding – Diluted (In Millions)		294.5			294.4			285.9

*	These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above.

Condensed Financial Information of Consolidated Edison, Inc.*

Condensed Statement of Cash Flows

(Parent Company Only)


(Millions of Dollars)	2012			2011			2010
Net Income	$	1,138		$	1,051		$	992
Equity in earnings of subsidiaries		(1,154	)		(1,064	)		(1,008	)
Dividends received from:
CECONY		682			681			670
O&R		34			33			32
Competitive energy businesses		11			12			8
Other – net		(208	)		(67	)		(4	)
Net Cash Flows from Operating Activities		503			646			690
Investing Activities
Contributions to subsidiaries		(100	)		-			(355	)
Net Cash Flows Used in Investing Activities		(100	)		-			(355	)
Financing Activities
Net proceeds of short-term debt		115			-			-
Retirement of long-term debt		(1	)		(1	)		(3	)
Issuance of common shares for stock plans, net of repurchases		(9	)		31			439
Common stock dividends		(709	)		(693	)		(629	)
Net Cash Flows Used in Financing Activities		(604	)		(663	)		(193	)
Net Change for the Period		(201	)		(17	)		142
Balance at Beginning of Period		205			222			80
Balance at End of Period	$	4		$	205		$	222

*	These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above.

Condensed Financial Information of Consolidated Edison, Inc.*

Condensed Balance Sheet

(Parent Company Only)


	At December 31,
(Millions of Dollars)	2012		2011
Assets
Current Assets
Cash and temporary cash investments	$	4	$	205
Accounts receivable – other		88		93
Accounts receivable from affiliated companies		393		208
Prepayments		51		36
Other current assets		54		61
Total Current Assets		590		603
Investments in subsidiaries and others		12,672		12,145
Goodwill		406		406
Deferred income tax		20		19
Other assets		4		4
Total Assets	$	13,692	$	13,177
Liabilities and Shareholders’ Equity
Current Liabilities
Long-term debt due within one year	$	2	$	1
Notes Payable		115		-
Accounts payable		5		5
Accounts payable to affiliated companies		146		143
Other current liabilities		214		240
Total Current Liabilities		482		389
Noncurrent Liabilities		-		-
Total Liabilities		482		389
Long-term debt		311		313
Shareholders’ Equity
Common stock		4,976		4,977
Retained earnings		7,923		7,498
Total Shareholders’ Equity		12,899		12,475
Total Liabilities and Shareholders’ Equity	$	13,692	$	13,177

*	These financial statements, in which Con Edison’s subsidiaries have been included using the equity method, should be read together with its consolidated financial statements and the notes thereto appearing above.

Schedule II Valuation and Qualifying Accounts

The entire disclosure for condensed financial information, including the financial position, cash flows, and the results of operations of the registrant (parent company) as of the same dates or for the same periods for which audited consolidated financial statements are being presented. Alternatively, the details of this disclosure can be reported by the specific parent company taxonomy elements, indicating the appropriate date and period contexts in an instance document.

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Schedule II Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2012

Schedule II

Valuation and Qualifying Accounts

For the Years Ended December 31, 2012, 2011 and 2010


					COLUMN C Additions
Company (Millions of Dollars)	COLUMN A Description		COLUMN B Balance at Beginning of Period		(1) Charged To Costs And Expenses		(2) Charged To Other Accounts		COLUMN D Deductions(b)		COLUMN E Balance At End of Period

Con Edison	Allowance for uncollectible accounts(a):
		2012	$	97	$	96		-	$	88	$	105
		2011	$	84	$	99		-	$	86	$	97
		2010	$	75	$	91		-	$	82	$	84
CECONY	Allowance for uncollectible accounts(a):
		2012	$	88	$	90		-	$	82	$	96
		2011	$	75	$	91		-	$	78	$	88
		2010	$	67	$	82		-	$	74	$	75

(a)	This is a valuation account deducted in the balance sheet from the assets (Accounts receivable-customers) to which they apply.

(b)	Accounts written off less cash collections, miscellaneous adjustments and amounts reinstated as receivables previously written off.

Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2012

Principles of Consolidation

Principles of Consolidation

Accounting Policies

Other significant accounting policies of the Companies are referenced below in this Note A and in the notes that follow.

Plant and Depreciation

Plant and Depreciation

Utility Plant

At December 31, 2012 and 2011, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Electric
Generation	$	434	$	400	$	434	$	400
Transmission		2,698		2,654		2,518		2,476
Distribution		14,658		13,805		13,930		13,125
Gas*		4,170		3,858		3,735		3,455
Steam		1,674		1,651		1,674		1,651
General		1,567		1,282		1,439		1,162
Held for future use		72		74		62		62
Construction work in progress		1,027		1,241		947		1,165
Net Utility Plant	$	26,300	$	24,965	$	24,739	$	23,496

*	Primarily distribution.

Non-Utility Plant

Goodwill

Goodwill

Impairments

Impairments

Revenues

Revenues

Public Utility Information

Recoverable Energy Costs

New York Independent System Operator (NYISO)

Temporary Cash Investments

Temporary Cash Investments

Investments

Investments

Pension and Other Postretirement Benefits

Pension and Other Postretirement Benefits

Income Taxes

Federal Income Tax

Accumulated deferred investment tax credits are amortized ratably over the lives of the related properties and applied as a reduction to future federal income tax expense.

State Income Tax

Research and Development Costs

Research and Development Costs

Generally research and development costs are charged to operating expenses as incurred. Research and development costs were as follows:


	For the Years Ended December 31,
(Millions of Dollars)	2012		2011		2010
Con Edison	$	21	$	23	$	23
CECONY		19		21		21

Reclassification

Reclassification

Certain prior year amounts have been reclassified to conform with the current year presentation.

Earnings Per Common Share

Earnings Per Common Share

Basic and diluted EPS for Con Edison are calculated as follows:


	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2010
Net income for common stock	$	1,138	$	1,051	$	992
Weighted average common shares outstanding – Basic		292.9		292.6		284.3
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.8		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		294.4		285.9
Net Income for common stock per common share – basic	$	3.88	$	3.59	$	3.49
Net Income for common stock per common share – diluted	$	3.86	$	3.57	$	3.47

Estimates

Estimates

Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2012

Capitalized Cost of Utility Plant

At December 31, 2012 and 2011, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Electric
Generation	$	434	$	400	$	434	$	400
Transmission		2,698		2,654		2,518		2,476
Distribution		14,658		13,805		13,930		13,125
Gas*		4,170		3,858		3,735		3,455
Steam		1,674		1,651		1,674		1,651
General		1,567		1,282		1,439		1,162
Held for future use		72		74		62		62
Construction work in progress		1,027		1,241		947		1,165
Net Utility Plant	$	26,300	$	24,965	$	24,739	$	23,496

*	Primarily distribution.

Research and Development Costs

Research and development costs were as follows:


	For the Years Ended December 31,
(Millions of Dollars)	2012		2011		2010
Con Edison	$	21	$	23	$	23
CECONY		19		21		21

Earnings Per Common Share

Basic and diluted EPS for Con Edison are calculated as follows:


	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2012		2011		2010
Net income for common stock	$	1,138	$	1,051	$	992
Weighted average common shares outstanding – Basic		292.9		292.6		284.3
Add: Incremental shares attributable to effect of potentially dilutive securities		1.6		1.8		1.6
Adjusted weighted average common shares outstanding – Diluted		294.5		294.4		285.9
Net Income for common stock per common share – basic	$	3.88	$	3.59	$	3.49
Net Income for common stock per common share – diluted	$	3.86	$	3.57	$	3.47

Regulatory Assets and Liabilities

Tabular disclosure of the effect of income (loss) on an entity's diluted earnings per share.

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Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2012

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2012 and 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	$	5,677	$	5,852	$	5,407	$	5,554
Future income tax		1,922		1,798		1,831		1,724
Environmental remediation costs		730		681		615		564
Deferred storm costs		432		128		309		80
Pension and other postretirement benefits deferrals		183		198		154		157
Revenue taxes		176		163		170		158
Net electric deferrals		102		121		102		121
Unamortized loss on reacquired debt		74		84		70		80
Surcharge for New York State assessment		73		90		68		82
Deferred derivative losses – long-term		40		60		20		44
O&R transition bond charges		39		44		-		-
Preferred stock redemption		29		-		29		-
Recoverable energy costs – long-term		23		14		23		14
Workers’ compensation		19		23		19		23
Property tax reconciliation		16		13		-		-
Other		170		162		155		149
Regulatory assets – long-term		9,705		9,431		8,972		8,750
Deferred derivative losses – current		69		164		60		140
Recoverable energy costs – current		5		-		-		-
Regulatory assets – current		74		164		60		140
Total Regulatory Assets	$	9,779	$	9,595	$	9,032	$	8,890
Regulatory liabilities
Allowance for cost of removal less salvage	$	503	$	448	$	420	$	372
Property tax reconciliation		187		35		187		35
Net unbilled revenue deferrals		136		104		136		104
World Trade Center settlement proceeds		62		62		62		62
Long-term interest rate reconciliation		62		30		62		30
Carrying charges on T&D net plant – electric and steam		31		38		13		14
Gas line losses		14		21		14		21
Expenditure prudence proceeding		14		11		14		11
Energy efficiency programs		5		22		6		20
Other		188		206		163		192
Regulatory liabilities – long-term		1,202		977		1,077		861
Refundable energy costs – current		82		51		48		12
Revenue decoupling mechanism		72		66		68		66
Electric surcharge offset		29		-		29		-
Deferred derivative gains – current		-		1		-		1
Regulatory liabilities – current		183		118		145		79
Total Regulatory Liabilities	$	1,385	$	1,095	$	1,222	$	940

CECONY - Electric [Member]

Schedule of Regulatory Liability Revenue Requirement Impact

The amounts reflected in rates are:


	Rate Year Ending March 31,
(Millions of Dollars)	2011		2012		2013
T&D	$	13,818	$	14,742	$	15,414
Other		1,487		1,565		1,650
ERP		-		25		115

CECONY - Steam [Member]

Schedule of Regulatory Liability Revenue Requirement Impact

The amounts reflected in rates are:


	Rate Year Ending September 30,
(Millions of Dollars)	2011		2012		2013
Steam production	$	415	$	426	$	433
Steam distribution		521		534		543

Capitalization (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Long-Term Debt Maturities

Long-term Debt

Long-term debt maturing in the period 2013-2017 is as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	706	$	700
2014		481		475
2015		495		350
2016		731		650
2017		7		-

Carrying Amounts and Fair Values of Long-Term Debt

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


	December 31,
(Millions of Dollars)	2012				2011
Long-Term Debt (including current portion)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Con Edison	$	10,768	$	12,935	$	10,673	$	12,744
CECONY	$	9,845	$	11,751	$	9,745	$	11,593

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

Companies' Net Periodic Benefit Costs

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

12 Months Ended

Dec. 31, 2012

Pension benefits [Member]

The components of the Companies’ net periodic benefit costs for 2012, 2011, and 2010 were as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
Service cost – including administrative expenses	$	237		$	190		$	168		$	220		$	177		$	157
Interest cost on projected benefit obligation		547			560			556			513			524			521
Expected return on plan assets		(705	)		(734	)		(704	)		(670	)		(698	)		(670	)
Recognition of net actuarial loss		709			530			425			670			501			401
Recognition of prior service costs		8			8			8			6			6			6
NET PERIODIC BENEFIT COST	$	796		$	554		$	453		$	739		$	510		$	415
Amortization of regulatory asset*		2			2			2			2			2			2
TOTAL PERIODIC BENEFIT COST	$	798		$	556		$	455		$	741		$	512		$	417
Cost capitalized		(277	)		(185	)		(157	)		(260	)		(172	)		(146	)
Reconciliation to rate level		(8	)		(65	)		(115	)		(12	)		(68	)		(113	)
Cost charged to operating expenses	$	513		$	306		$	183		$	469		$	272		$	158

*	Relates to an increase in CECONY’s pension obligation of $45 million from a 1999 special retirement program.

Schedule of Funded Status

The funded status at December 31, 2012, 2011, and 2010 was as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$	11,825		$	10,307		$	9,408		$	11,072		$	9,653		$	8,803
Service cost – excluding administrative expenses		224			186			160			209			174			149
Interest cost on projected benefit obligation		547			560			556			513			524			521
Plan amendments		-			-			6			-			-			-
Net actuarial loss		1,323			1,251			636			1,255			1,166			607
Benefits paid		(513	)		(479	)		(459	)		(477	)		(445	)		(427	)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$	13,406		$	11,825		$	10,307		$	12,572		$	11,072		$	9,653
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$	7,800		$	7,721		$	6,877		$	7,406		$	7,340		$	6,544
Actual return on plan assets		1,094			37			888			1,040			33			846
Employer contributions		785			542			443			729			498			404
Benefits paid		(513	)		(479	)		(459	)		(477	)		(445	)		(427	)
Administrative expenses		(31	)		(21	)		(28	)		(30	)		(20	)		(27	)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$	9,135		$	7,800		$	7,721		$	8,668		$	7,406		$	7,340
FUNDED STATUS	$	(4,271	)	$	(4,025	)	$	(2,586	)	$	(3,904	)	$	(3,666	)	$	(2,313	)
Unrecognized net loss	$	5,594		$	5,351		$	3,915		$	5,297		$	5,063		$	3,716
Unrecognized prior service costs		23			30			38			10			16			22
Accumulated benefit obligation		11,911			10,595			9,319			11,116			9,876			8,694

Schedule of Assumptions

The actuarial assumptions were as follows:


	2012			2011			2010
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate		4.10	%		4.70	%		5.60	%
Rate of compensation increase
– CECONY		4.35	%		4.35	%		4.35	%
– O&R		4.25	%		4.25	%		4.25	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate		4.70	%		5.60	%		6.05	%
Expected return on plan assets		8.00	%		8.50	%		8.50	%
Rate of compensation increase
– CECONY		4.35	%		4.35	%		4.00	%
– O&R		4.25	%		4.25	%		4.00	%

Schedule of Expected Benefit Payments

Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years:


(Millions of Dollars)	2013		2014		2015		2016		2017		2018-2022
Con Edison	$	554	$	582	$	608	$	634	$	659	$	3,635
CECONY		517		542		567		591		614		3,394

Schedule of Plan Assets Allocations

The asset allocations for the pension plan at the end of 2012, 2011, and 2010, and the target allocation for 2013 are as follows:


	Target Allocation Range		Plan Assets at December 31
Asset Category	2013		2012			2011			2010
Equity Securities		55% - 65%		60	%		61	%		67	%
Debt Securities		27% - 33%		31	%		32	%		28	%
Real Estate		8% - 12%		9	%		7	%		5	%
Total		100%		100	%		100	%		100	%

Schedule of Fair Value of Plan Assets

The fair values of the pension plan assets at December 31, 2012 by asset category are as follows:


(Millions of Dollars)	Level 1			Level 2			Level 3			Total
U.S. Equity(a)	$	2,637		$	-		$	-		$	2,637
International Equity(b)		2,242			753			-			2,995
Private Equity(c)		-			-			20			20
U.S. Government Issues(d)		-			1,626			-			1,626
Corporate Bonds(e)		-			993			-			993
Structured Assets(f)		-			30			-			30
Other Fixed Income(g)		-			123			-			123
Real Estate(h)		-			-			833			833
Cash and Cash Equivalents(i)		83			328			-			411
Futures(j)		210			-			-			210
Total investments	$	5,172		$	3,853		$	853		$	9,878
Funds for retiree health benefits(k)		(185	)		(137	)		(31	)		(353	)
Investments (excluding funds for retiree health benefits)	$	4,987		$	3,716		$	822		$	9,525
Pending activities(l)											(390	)
Total fair value of plan net assets										$	9,135

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities.

(b)	International Equity includes international equity index funds and actively-managed international equities.

(c)	Private Equity consists of global equity funds that are not exchange-traded.

(d)	U.S. Government Issues include agency and treasury securities.

(e)	Corporate Bonds consist of debt issued by various corporations.

(f)	Structured Assets include commercial-mortgage-backed securities and collateralized mortgage obligations.

(g)	Other Fixed Income includes municipal bonds, sovereign debt and regional governments.

(h)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.

(i)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.

(j)	Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.

(k)

(l)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.

The fair values of the pension plan assets at December 31, 2011 by asset category are as follows:


(Millions of Dollars)	Level 1			Level 2			Level 3			Total
U.S. Equity(a)	$	2,467		$	-		$	-		$	2,467
International Equity(b)		1,850			637			-			2,487
U.S. Government Issues(c)		-			1,570			-			1,570
Corporate Bonds(d)		-			668			94			762
Structured Assets(e)		-			-			13			13
Other Fixed Income(f)		-			67			29			96
Real Estate(g)		-			-			572			572
Cash and Cash Equivalents(h)		13			395			-			408
Futures(i)		93			48			-			141
Total investments	$	4,423		$	3,385		$	708		$	8,516
Funds for retiree health benefits(j)		(174	)		(134	)		(28	)		(336	)
Investments (excluding funds for retiree health benefits)	$	4,249		$	3,251		$	680		$	8,180
Pending activities(k)											(380	)
Total fair value of plan net assets										$	7,800

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and actively-managed small-capitalization equities.

(b)	International Equity includes international equity index funds and actively-managed international equities.

(c)	U.S. Government Issues include agency and treasury securities.

(d)	Corporate Bonds classified as Level 3 include 144A illiquid securities.

(e)	Structured Assets include commercial-mortgage-backed securities and collateralized mortgage obligations.

(f)	Other Fixed Income includes municipal bonds, sovereign debt and regional governments.

(g)	Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.

(h)	Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.

(i)	Futures consist of exchange-traded financial contracts encompassing U.S. equity, International equity and U.S. Government indices.

(j)

(k)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received and reflects adjustments for available estimates at year end.

Reconciliation of Fair Value Balances for Net Assets

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2012 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2012			Assets Still Held at Reporting Date – Unrealized Gains/(Losses)			Assets Sold During the Period – Realized Gains			Purchases Sales and Settlements			Transfer in/(out) of Level 3			Ending Balance as of December 31, 2012
Real Estate	$	572		$	48		$	1		$	212		$	-		$	833
Private Equity		-			1			-			19			-			20
Corporate Bonds		94			-			-			(33	)		(61	)		-
Structured Assets		13			-			(6	)		-			(7	)		-
Other Fixed Income		29			-			-			(6	)		(23	)		-
Total investments	$	708		$	49		$	(5	)	$	192		$	(91	)	$	853
Funds for retiree health benefits		(28	)		(2	)		-			(4	)		3			(31	)
Investments (excluding funds for retiree health benefits)	$	680		$	47		$	(5	)	$	188		$	(88	)	$	822

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2011 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2011			Assets Still Held at Reporting Date – Unrealized Gains/(Losses)			Assets Sold During the Period – Realized Gains		Purchases Sales and Settlements			Ending Balance as of December 31, 2011
Real Estate	$	398		$	65		$	-	$	109		$	572
Corporate Bonds		129			(9	)		11		(37	)		94
Other Fixed Income		66			(1	)		3		(39	)		29
Structured Assets		87			(1	)		2		(75	)		13
Total investments	$	680		$	54		$	16	$	(42	)	$	708
Funds for retiree health benefits		(30	)		3			1		(2	)		(28	)
Investments (excluding funds for retiree health benefits)	$	650		$	57		$	17	$	(44	)	$	680

Schedule of Employer Contribution to Defined Savings Plan

The Companies also offer a defined contribution savings plan that covers substantially all employees and made contributions to the plan as follows:


	For the Years Ended December 31
(Millions of Dollars)	2012		2011		2010
Con Edison	$	23	$	23	$	19
CECONY		21		21		17

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

12 Months Ended

Dec. 31, 2012

Other Postretirement Benefits [Member]

Net Periodic Postretirement Benefit Costs

The components of the Companies’ net periodic postretirement benefit costs for 2012, 2011, and 2010 were as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
Service cost	$	26		$	26		$	24		$	21		$	20		$	19
Interest cost on accumulated other postretirement benefit obligation		73			83			91			63			72			80
Expected return on plan assets		(85	)		(88	)		(86	)		(75	)		(78	)		(78	)
Recognition of net actuarial loss		98			88			92			87			80			85
Recognition of prior service cost		(21	)		(10	)		(12	)		(18	)		(11	)		(14	)
Recognition of transition obligation		2			4			3			2			4			3
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	93		$	103		$	112		$	80		$	87		$	95
Cost capitalized		(32	)		(35	)		(39	)		(28	)		(29	)		(33	)
Reconciliation to rate level		20			14			4			16			13			1
Cost charged to operating expenses	$	81		$	82		$	77		$	68		$	71		$	63

Schedule of Funded Status

The funded status of the programs at December 31, 2012, 2011, and 2010 were as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$	1,756		$	1,642		$	1,697		$	1,511		$	1,426		$	1,495
Service cost		26			25			24			21			20			19
Interest cost on accumulated postretirement benefit obligation		73			83			91			63			72			80
Amendments		(127	)		-			-			(89	)		-			-
Net actuarial loss/(gain)		(175	)		109			(68	)		(178	)		86			(77	)
Benefits paid and administrative expenses		(146	)		(144	)		(138	)		(134	)		(132	)		(126	)
Participant contributions		37			33			29			36			32			28
Medicare prescription subsidy		10			8			7			8			7			7
BENEFIT OBLIGATION AT END OF YEAR	$	1,454		$	1,756		$	1,642		$	1,238		$	1,511		$	1,426
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$	947		$	942		$	866		$	840		$	839		$	777
Actual return on plan assets		124			20			89			109			19			78
Employer contributions		83			84			96			71			74			85
Participant contributions		37			33			29			36			32			28
Benefits paid		(144	)		(132	)		(138	)		(134	)		(124	)		(129	)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$	1,047		$	947		$	942		$	922		$	840		$	839
FUNDED STATUS	$	(407	)	$	(809	)	$	(700	)	$	(316	)	$	(671	)	$	(587	)
Unrecognized net loss	$	251		$	563		$	483		$	197		$	496		$	440
Unrecognized prior service costs		(105	)		(1	)		(10	)		(84	)		(15	)		(26	)
Unrecognized net transition liability at January 1, 1993		-			4			7			-			4			7

Schedule of Assumptions

The actuarial assumptions were as follows:


	2012			2011			2010
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY		3.75	%		4.55	%		5.40	%
O&R		4.05	%		4.55	%		5.40	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate		4.55%			5.40%			5.95%
Expected Return on Plan Assets		8.50%			8.50%			8.50%

Schedule of Change of Assumed Health Care Cost Trend Rate

A one-percentage point change in the assumed health care cost trend rate would have the following effects at December 31, 2013:


	Con Edison					CECONY
	1-Percentage-Point
(Millions of Dollars)	Increase			Decrease		Increase			Decrease
Effect on accumulated other postretirement benefit obligation	$	(12	)	$	12	$	(31	)	$	27
Effect on service cost and interest cost components for 2012		-			-		(2	)		1

Schedule of Expected Benefit Payments

Based on current assumptions, the Companies expect to make the following benefit payments over the next ten years, net of receipt of governmental subsidies:


(Millions of Dollars)	2013		2014		2015		2016		2017		2018-2022
BENEFIT PAYMENTS
Con Edison	$	101	$	101	$	101	$	98	$	97	$	452
CECONY		91		90		89		87		86		389

Schedule of Plan Assets Allocations

The asset allocations for CECONY’s other postretirement benefit plans at the end of 2012, 2011, and 2010, and the target allocation for 2013 are as follows:


	Target Allocation Range			Plan Assets at December 31
Asset Category	2013			2012			2011			2010
Equity Securities		57	% - 73%		62	%		62	%		67%
Debt Securities		26	% - 44%		38	%		38	%		33%
Total		100	%		100	%		100	%		100%

Schedule of Fair Value of Plan Assets

The fair values of the plan assets at December 31, 2012 by asset category (see description of levels in Note E) are as follows:


(Millions of Dollars)	Level 1		Level 2		Level 3		Total
U.S. Equity(a)	$	127	$	184	$	-	$	311
International Equity(b)		-		124		-		124
Other Fixed Income(c)		-		229		-		229
Cash and Cash Equivalents(d)		-		23		-		23
Total investments	$	127	$	560	$	-	$	687
Funds for retiree health benefits(e)		185		137		31		353
Investments (including funds for retiree health benefits)	$	312	$	697	$	31	$	1,040
Pending activities(f)								7
Total fair value of plan net assets							$	1,047

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and commingled funds.

(b)	International Equity includes commingled international equity funds.

(c)	Other Fixed Income includes commingled funds, which are valued at Net Asset Value.

(d)	Cash and Cash Equivalents include short term investments and money markets.

(e)

(f)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received, and reflects adjustments for available estimates at year end.

The fair values of the plan assets at December 31, 2011 by asset category (see description of levels in Note E) are as follows:


(Millions of Dollars)	Level 1		Level 2		Level 3		Total
U.S. Equity(a)	$	115	$	162	$	-	$	277
International Equity(b)		-		104		-		104
Other Fixed Income(c)		-		207		-		207
Cash and Cash Equivalents(d)		-		18		-		18
Total investments	$	115	$	491	$	-	$	606
Funds for retiree health benefits(e)		174		134		28		336
Investments (including funds for retiree health benefits)	$	289	$	625	$	28	$	942
Pending activities(f)								5
Total fair value of plan net assets							$	947

(a)	U.S. Equity includes both actively- and passively-managed assets with investments in domestic equity index funds and commingled funds.

(b)	International Equity includes commingled international equity funds.

(c)	Other Fixed Income includes commingled funds, which are valued at Net Asset Value.

(d)	Cash and Cash Equivalents include short term investments and money markets.

(e)

(f)	Pending activities include security purchases and sales that have not settled, interest and dividends that have not been received, and reflects adjustments for available estimates at year end.

Reconciliation of Fair Value Balances for Net Assets

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2012 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2012		Assets Still Held at Reporting Date – Unrealized Gains/(Losses)		Assets Sold During the Period – Realized (Losses)		Purchases Sales and Settlements		Transfers Out of Level 3			Ending Balance as of December 31, 2012
Other Fixed Income	$	-	$	-	$	-	$	-	$	-		$	-
Insurance Contracts		-				-		-		-			-
Total investments	$	-	$	-	$	-	$	-	$	-		$	-
Funds for retiree health benefits		28		2		-		4		(3	)		31
Investments (including funds for retiree health benefits)	$	28	$	2	$	-	$	4	$	(3	)	$	31

The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2011 classified as Level 3 in the fair value hierarchy.


(Millions of Dollars)	Beginning Balance as of January 1, 2011		Assets Still Held at Reporting Date — Unrealized Gains/(Losses)			Assets Sold During the Period — Realized (Losses)			Purchases Sales and Settlements		Transfers Out of Level 3			Ending Balance as of December 31, 2011
Other Fixed Income	$	189	$	-		$	-		$	-	$	(189	)	$	-
Insurance Contracts		-		-			-			-		-			-
Total investments	$	189	$	-		$	-		$	-	$	(189	)	$	-
Funds for retiree health benefits		30		(3	)		(1	)		2		-			28
Investments (including funds for retiree health benefits)	$	219	$	(3	)	$	(1	)	$	2	$	(189	)	$	28

Tabular disclosure of one or more of the entity's defined benefit pension plans or one or more other defined benefit postretirement plans, separately for pension plans and other postretirement benefit plans including the entity's schedule of fair value of plan assets for defined benefit or other postretirement plans.

Accrued Liabilities and Regulatory Assets

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Reference 7: http://www.xbrl.org/2003/role/presentationRef

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+ Details

Environmental Matters (Tables)

12 Months Ended

Dec. 31, 2012

The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2012 and 2011 were as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Accrued Liabilities:
Manufactured gas plant sites	$	462	$	422	$	351	$	307
Other Superfund Sites		83		67		82		66
Total	$	545	$	489	$	433	$	373
Regulatory assets	$	730	$	681	$	615	$	564

Environmental Remediation Costs

Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites at December 31, 2012 and 2011 were as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Remediation costs incurred	$	31	$	39	$	26	$	35
Insurance recoveries received*		4		-		4		-

*	Reduced amount deferred for recovery from customers

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 December 31, 2012 and 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

Other Material Contingencies (Tables)

12 Months Ended

Dec. 31, 2012

Total Guarantees

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


Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	(Millions of Dollars)
Energy transactions	$	716	$	25	$	62	$	803
Intra-company guarantees		15		-		1		16
Other guarantees		35		5		-		40
Total	$	766	$	30	$	63	$	859

Summary of Significant Terms of Electricity Purchase Agreement

Tabular disclosure of each guarantee obligation, or each group of similar guarantee obligations, including (a) the nature of the guarantee, including its term, how it arose, and the events or circumstances that would require the guarantor to perform under the guarantee; (b) the maximum potential amount of future payments (undiscounted) the guarantor could be required to make under the guarantee; (c) the current carrying amount of the liability, if any, for the guarantor's obligations under the guarantee; and (d) the nature of any recourse provisions under the guarantee, and any assets held either as collateral or by third parties, and any relevant related party disclosure. Excludes disclosures about product warranties.

+ References+ Details

Electricity Purchase Agreements (Tables)

12 Months Ended

Dec. 31, 2012

At December 31, 2012, the significant terms of the electricity purchase agreements were as follows:


Facility	Equity Owner	Plant Output (MW)		Contracted Output (MW)			Contract Start Date		Contract Term (Years)
Indian Point	Entergy Nuclear Power Marketing, LLC		1,299		350	*		August 2001		16
Independence	Sithe/Independence Power Partners, LP		1,254		697			November 1994		20
Linden Cogeneration	Cogen Technologies Linden Venture, LP		1,035		628			May 1992		25
Astoria Energy	Astoria Energy, LLC		640		500			May 2006		10
Selkirk	Selkirk Cogen Partners, LP		446		265			September 1994		20
Brooklyn Navy Yard	Brooklyn Navy Yard Cogeneration Partners, LP		322		263			November 1996		40
Indeck Corinth	Indeck Energy Services of Corinth, Inc.		147		132			July 1995		20

Summary of Estimated Capacity and Other Fixed Payments

The future capacity and other fixed payments under the contracts are estimated to be as follows:

(Millions of
Dollars)

2013

2014

2015

2016

2017

All Years

Thereafter

CECONY

507

446

229

165

110

933

Summary of Capacity, Energy and Other Fixed Payments

The company’s payments under the agreements for capacity, energy and other fixed payments in 2012, 2011, and 2010 were as follows:


	For the Years Ended December 31,
(Millions of Dollars)	2012		2011		2010
Linden	$	297	$	379	$	414
Indian Point		204		238		524
Selkirk		196		209		185
Astoria		181		225		223
Independence		127		121		119
Brooklyn Navy Yard		93		123		123
Indeck Corinth		66		77		68
Total	$	1,164	$	1,372	$	1,656

Schedule of Capital Leases

Tabular disclosure of information concerning the terms and significance of long term contracts to purchase power (generally referred to as purchase power agreements (PPAs) or power sale agreements (PSAs)) including date of contract expiration, share of plant output being purchased, estimated annual cost, annual minimum debt service payment required and amount of related long-term debt or lease obligations outstanding.

+ References+ Details

Leases (Tables)

12 Months Ended

Dec. 31, 2012

The following assets under capital leases are included in the Companies’ consolidated balance sheets at December 31, 2012 and 2011:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
UTILITY PLANT
Common	$	3	$	8	$	2	$	6
Transmission		-		1		-		1
TOTAL	$	3	$	9	$	2	$	7

Future Minimum Lease Commitments

The future minimum lease commitments for the above assets are as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	-	$	-
2014		1		1
2015		1		1
2016		-		-
2017		-		-
All years thereafter		1		1
Total		3		3
Less: amount representing interest		1		1
Present value of net minimum lease payment	$	2	$	2

Future Minimum Rental Payments for Operating Leases

The future minimum lease commitments under the Companies’ non-cancelable operating lease agreements are as follows:


(Millions of Dollars)	Con Edison		CECONY
2013	$	52	$	49
2014		47		43
2015		15		12
2016		14		11
2017		14		11
All years thereafter		91		71
Total	$	233	$	197

Income Tax (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Components of Income Tax

The components of income tax are as follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
State
Current	$	29		$	56		$	23		$	53		$	53		$	13
Deferred		97			63			106			53			55			100
Federal
Current		(13	)		53			(144	)		110			43			(139	)
Deferred		493			434			569			318			413			527
Amortization of investment tax credits		(6	)		(6	)		(6	)		(5	)		(6	)		(6	)
Total charge to income tax expense	$	600		$	600		$	548		$	529		$	558		$	495

Schedule of Differences on Deferred Tax Assets and Liabilities

The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows:


	Con Edison						CECONY
(Millions of Dollars)	2012			2011			2012			2011
Deferred tax liabilities:
Depreciation	$	4,210		$	3,652		$	3,909		$	3,464
Regulatory asset – future income tax		2,061			1,971			1,962			1,891
Unrecognized pension and other postretirement costs		2,472			2,554			2,202			2,255
State income tax		1,060			920			897			811
Capitalized overheads		565			536			496			470
Pension		736			682			730			709
Investment tax credits		49			55			47			52
Other		931			743			528			467
Total deferred tax liabilities		12,084			11,113			10,771			10,119
Deferred tax assets:
Unrecognized pension and other postretirement costs		2,472			2,554			2,202			2,255
State income tax		382			336			357			309
Regulatory liability – future income tax		126			173			117			167
Other		1,028			753			836			624
Total deferred tax assets		4,008			3,816			3,512			3,355
Net deferred tax liabilities and investment tax credits	$	8,076		$	7,297		$	7,259		$	6,764
Deferred income taxes and investment tax credits – Noncurrent	$	8,372		$	7,563		$	7,452		$	6,921
Deferred tax assets – Current		(296	)		(266	)		(193	)		(157	)
Net deferred tax liabilities and investment tax credits	$	8,076		$	7,297		$	7,259		$	6,764

Schedule of Income Tax Reconciliation

Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes is as follows:


	Con Edison									CECONY
(% of Pre-tax income)	2012			2011			2010			2012			2011			2010
STATUTORY TAX RATE
Federal		35	%		35	%		35	%		35	%		35	%		35	%
Changes in computed taxes resulting from:
State income tax		4			5			5			4			5			5
Cost of removal		(4	)		(4	)		(4	)		(4	)		(4	)		(4	)
Other		(1	)		-			(1	)		(1	)		-			(1	)
Effective Tax Rate		34	%		36	%		35	%		34	%		36	%		35	%

Summary of Unrecognized Tax Benefits

A reconciliation of the beginning and ending amounts of unrecognized tax benefits for Con Edison and CECONY follows:


	Con Edison									CECONY
(Millions of Dollars)	2012			2011			2010			2012			2011			2010
Balance at January 1	$	130		$	93		$	86		$	114		$	79		$	92
Additions based on tax positions related to the current year		12			76			5			11			74			4
Additions based on tax positions of prior years		-			4			67			-			3			49
Reductions for tax positions of prior years		(57	)		(43	)		(4	)		(52	)		(42	)		(4	)
Settlements		1			-			(61	)		1			-			(62	)
Balance at December 31	$	86		$	130		$	93		$	74		$	114		$	79

Stock-Based Compensation Expense

Tabular disclosure of tax positions taken in the tax returns filed or to be filed for which it is more likely than not that the tax position will not be sustained upon examination by taxing authorities (i.e., uncertain tax positions) and other types of income tax contingencies, including: (1) the policy on classification of interest and penalties; (2) a tabular reconciliation of the total amounts of unrecognized tax benefits at the beginning and end of the period; the total amount(s) of: (3) unrecognized tax benefits that, if recognized, would affect the effective tax rate, and (4) interest and penalties recognized in each of the income statement and balance sheet; (5) for positions for which it is reasonably possible that the total amounts unrecognized will significantly change within 12 months of the reporting date the: (i) nature of the uncertainty, (ii) nature of the event that could occur that would cause the change, and (iii) an estimate of the range of the reasonably possible change or a statement that an estimate of the range cannot be made; and (6) a description of tax years that remain subject to examination by major tax jurisdictions.

+ References+ Details

Stock-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2012

The following table summarizes stock-based compensation expense recognized by the Companies in the period ended December 31, 2012, 2011, and 2010:


	Con Edison						CECONY
(Millions of Dollars)	2012		2011		2010		2012		2011		2010
Performance-based restricted stock	$	14	$	48	$	27	$	13	$	44	$	25
Restricted stock units		1		3		1		1		3		1
Non-officer director deferred stock compensation		1		1		1		1		1		1
Total	$	16	$	52	$	29	$	15	$	48	$	27
Income Tax Benefit	$	6	$	21	$	12	$	6	$	20	$	11

Summary of Status of Stock Options Awarded

A summary of changes in the status of stock options awarded as of December 31, 2012 is as follows:


	Con Edison					CECONY
	Shares			Weighted Average Exercise Price		Shares			Weighted Average Exercise Price
Outstanding at 12/31/11		927,025		$	43.046		740,875		$	43.066
Exercised		(318,550	)		43.128		(258,700	)		43.238
Forfeited		(2,000	)		41.665		(1,000	)		43.005
Outstanding at 12/31/12		606,475		$	43.008		481,175		$	42.973

Summary of Stock Options Outstanding

The following table summarizes stock options outstanding at December 31, 2012 for each plan year for the Companies:


			Con Edison				CECONY
Plan Year	Remaining Contractual Life		Options Outstanding/ Exercisable		Weighted Average Exercise Price		Options Outstanding/ Exercisable		Weighted Average Exercise Price
2006		3		228,250	$	43.870		188,150	$	43.841
2005		2		170,125		42.243		139,025		42.258
2004		1		157,000		44.060		112,400		44.072
2003		<1		51,100		38.470		41,600		38.470
Total				606,475	$	43.008		481,175	$	42.973

Assumptions Used to Calculate Fair Value

The following table illustrates the assumptions used to calculate the fair value of the awards:


	2012
Risk-free interest rate		0.15% - 3.69%
Expected term		3 years
Expected volatility		15.27%

Restricted Stock Units [Member]

Summary of Changes in Status of Restricted Stock

A summary of changes in the status of restricted stock (other than Performance RSUs or awards under the directors’ deferred compensation plan) during the period ended December 31, 2012 is as follows:


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value		Units			Weighted Average Grant Date Fair Value
Non-vested at 12/31/11		65,420		$	45.049		61,920		$	45.049
Granted		22,860			58.420		21,660			58.420
Vested		(21,130	)		39.610		(19,980	)		39.610
Forfeited		(2,010	)		50.452		(1,910	)		50.600
Non-vested at 12/31/12		65,140		$	51.339		61,690		$	51.334

TSR portion [Member]

Summary of Changes in Status of Performance RSUs

A summary of changes in the status of the Performance RSUs TSR portion during the period ended December 31, 2012 is as follows:


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value*		Units			Weighted Average Grant Date Fair Value*
Non-vested at 12/31/11		474,517		$	42.511		387,379		$	42.542
Granted		191,280			49.507		157,348			49.416
Vested		(36,075	)		41.868		(33,653	)		41.869
Forfeited		(10,812	)		45.452		(8,373	)		46.023
Non-vested at 12/31/12		618,910		$	44.659		502,701		$	44.681

*	Fair value is determined using the Monte Carlo simulation described above. Weighted average grant date fair value does not reflect any accrual or payment of dividends prior to vesting.

EIP portion [Member]

Summary of Changes in Status of Performance RSUs

A summary of changes in the status of the Performance RSUs’ EIP portion during the period ended December 31, 2012 is as follows:


	Con Edison					CECONY
	Units			Weighted Average Grant Date Fair Value*		Units			Weighted Average Grant Date Fair Value*
Non-vested at 12/31/11		474,517		$	46.660		387,379		$	46.599
Granted		191,280			58.852		157,348			58.838
Vested		(36,075	)		39.663		(33,653	)		39.666
Forfeited		(10,812	)		52.247		(8,373	)		53.183
Non-vested at 12/31/12		618,910		$	50.738		502,701		$	50.783

*	Fair value is determined using the market price of one share of Con Edison common stock on the grant date. The market price has not been discounted to reflect that dividends do not accrue and are not payable on Performance RSUs until vesting.

Financial Data for the Business Segments

Tabular disclosure of components of a stock option or other award plan under which equity-based compensation is awarded to employees, typically comprised of the amount of unearned compensation (deferred compensation cost), compensation expense, and changes in the quantity and fair value of the shares (or other type of equity) granted, exercised, forfeited, and issued and outstanding pertaining to that plan. Disclosure may also include nature and general terms of such arrangements that existed during the period and potential effects of those arrangements on shareholders, effect of compensation cost arising from equity-based payment arrangements on the income statement, method of estimating the fair value of the goods or services received, or the fair value of the equity instruments granted, during the period, cash flow effects resulting from equity-based payment arrangements and, for registrants that accelerate vesting of out of the money share options, reasons for the decision to accelerate.

+ References+ Details

Financial Information by Business Segment (Tables)

12 Months Ended

Dec. 31, 2012

The financial data for the business segments are as follows:


As of and for the Year Ended December 31, 2012 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,176		$	15		$	710	$	1,693		$	423		$	393	$	28,339	$	1,375
Gas		1,415			5			120		346			82			99		5,925		426
Steam		596			77			64		54			40			22		2,621		108
Consolidation adjustments		-			(97	)		-		-			-			-		-		-
Total CECONY	$	10,187		$	-		$	894	$	2,093		$	545		$	514	$	36,885	$	1,909
O&R
Electric	$	592		$	-		$	38	$	83		$	19		$	17	$	1,960	$	98
Gas		203			-			15		40			10			11		706		39
Other*		-			-			-		-			2			-		5		-
Total O&R	$	795		$	-		$	53	$	123		$	31		$	28	$	2,671	$	137
Competitive energy businesses	$	1,213		$	8		$	8	$	125		$	1		$	52	$	1,061	$	492
Other**		(7	)		(8	)		-		(2	)		27			-		592		-
Total Con Edison	$	12,188		$	-		$	955	$	2,339		$	604		$	594	$	41,209	$	2,538
As of and for the Year Ended December 31, 2011 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,228		$	12		$	656	$	1,695		$	414		$	481	$	27,123	$	1,354
Gas		1,521			5			110		295			78			43		5,518		335
Steam		683			79			63		93			42			43		2,577		89
Consolidation adjustments		-			(96	)		-		-			-			-		-		-
Total CECONY	$	10,432		$	-		$	829	$	2,083		$	534		$	567	$	35,218	$	1,778
O&R
Electric	$	641		$	-		$	35	$	81		$	20		$	21	$	1,755	$	79
Gas		214			-			13		33			12			9		722		32
Other*		-			-			-		-			2			-		8		-
Total O&R	$	855		$	-		$	48	$	114		$	34		$	30	$	2,485	$	111
Competitive energy businesses	$	1,617		$	13		$	7	$	46		$	(1	)	$	20	$	856	$	114
Other**		(18	)		(13	)		-		(4	)		27			-		655		-
Total Con Edison	$	12,886		$	-		$	884	$	2,239		$	594		$	617	$	39,214	$	2,003
As of and for the Year Ended December 31, 2010 (Millions of Dollars)	Operating revenues			Inter-segment revenues			Depreciation and amortization		Operating income			Interest charges			Income tax expense		Total assets*		Construction expenditures
CECONY
Electric	$	8,376		$	12		$	623	$	1,549		$	424		$	371	$	25,045	$	1,421
Gas		1,541			5			102		310			82			91		5,095		334
Steam		656			74			62		63			43			29		2,465		111
Consolidation adjustments		-			(91	)		-		-			-			-		-		-
Total CECONY	$	10,573		$	-		$	787	$	1,922		$	549		$	491	$	32,605	$	1,866
O&R
Electric	$	692		$	-		$	32	$	74		$	22		$	18	$	1,630	$	99
Gas		218			-			12		34			12			8		686		36
Other*		-			-			-		-			1			-		32		-
Total O&R	$	910		$	-		$	44	$	108		$	35		$	26	$	2,348	$	135
Competitive energy businesses	$	1,883		$	9		$	9	$	97		$	(3	)	$	37	$	828	$	28
Other**		(41	)		(9	)		-		(7	)		28			-		567		-
Total Con Edison	$	13,325		$	-		$	840	$	2,120		$	609		$	554	$	36,348	$	2,029

*	Includes amounts related to the RECO securitization.

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

Energy Price Hedging Fair Values

Tabular disclosure of the profit or loss and total assets for each reportable segment. An entity discloses certain information on each reportable segment if the amounts (a) are included in the measure of segment profit or loss reviewed by the chief operating decision maker or (b) are otherwise regularly provided to the chief operating decision maker, even if not included in that measure of segment profit or loss.

+ References+ Details

Derivative Instruments and Hedging Activities (Tables)

12 Months Ended

Dec. 31, 2012

The fair values of these hedges at December 31, 2012 and 2011 were as follows:


	Con Edison				CECONY
(Millions of Dollars)	2012		2011		2012		2011
Fair value of net derivative assets/(liabilities) – gross	$	(90)	$	(249)	$	(56)	$	(144)
Impact of netting of cash collateral		84		110		47		46
Fair value of net derivative assets/(liabilities) – net	$	(6)	$	(139)	$	(9)	$	(98)

Fair Values of Companies' Commodity Derivatives

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


	Fair Value of Commodity Derivatives(a)
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
	Derivative Assets
Current	Other current assets	$	64		$	18
Long-term	Other deferred charges and noncurrent assets		22			9
Total derivative assets		$	86		$	27
Impact of netting			(20	)		3
Net derivative assets		$	66		$	30
	Derivative Liabilities
Current	Fair value of derivative liabilities	$	122		$	58
Long-term	Fair value of derivative liabilities		54			25
Total derivative liabilities		$	176		$	83
Impact of netting			(104	)		(44	)
Net derivative liabilities		$	72		$	39

(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:


	Fair Value of Commodity Derivatives(a)
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
	Derivative Assets
Current	Other current assets	$	139		$	16
Long-term	Other deferred charges and noncurrent 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 table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the year ended December 31, 2012:


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Year Ended December 31, 2012
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(1	)	$	(1	)
Long-term	Regulatory liabilities		-			-
Total deferred gains/(losses)		$	(1	)	$	(1	)
Current	Deferred derivative losses	$	95		$	80
Current	Recoverable energy costs		(220	)		(192	)
Long-term	Deferred derivative losses		17			24
Total deferred gains/(losses)		$	(108	)	$	(88	)
Net deferred gains/(losses)		$	(109	)	$	(89	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(54	)(b)	$	-
	Gas purchased for resale		(5	)		-
	Non-utility revenue		(11	)(b)		-
Total pre-tax gain/(loss) recognized in income		$	(70	)	$	-

(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 year ended December 31, 2012, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(14) million and $82 million, respectively.

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


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Year Ended December 31, 2011
(Millions of Dollars)	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(3	)	$	(2	)
Long-term	Regulatory liabilities		(1	)		(1	)
Total deferred gains/(losses)		$	(4	)	$	(3	)
Current	Deferred derivative losses	$	26		$	11
Current	Recoverable energy costs		(247	)		(185	)
Long-term	Deferred derivative losses		11			4
Total deferred gains/(losses)		$	(210	)	$	(170	)
Net deferred gains/(losses)		$	(214	)	$	(173	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(78	)(b)	$	-
	Gas purchased for resale		(18	)		-
	Non-utility revenue		(30	)(b)		-
Total pre-tax gain/(loss) recognized in income		$	(126	)	$	-

(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 year ended December 31, 2011, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(34) million and $11 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)		MWs(b)		Number of Contracts(a)		Dths(b)		Total Number Of Contracts(a)
Con Edison		496		15,761,464		59		11,668		592		84,706,809		1,147
CECONY		97		3,565,325		-		-		484		79,460,000		581

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

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

Aggregate Fair Value of All Derivative Instruments with Credit-Risk-Related Contingent Features


(Millions of Dollars)	Con Edison(a)			CECONY(a)
Aggregate fair value – net liabilities	$	52		$	39
Collateral posted	$	-		$	-
Additional collateral^(b) (downgrade one level from current ratings)	$	4		$	4
Additional collateral^(b) (downgrade to below investment grade from current ratings)	$	77	(c)	$	43	(c)

(a)

(b)

(c)	Derivative instruments that are net assets have been excluded from the table. At December 31, 2012, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $24 million, including $1 million for CECONY.

Tabular disclosure of credit derivatives which includes information by sellers of credit derivatives, about each credit derivative, or each group of similar credit derivatives, including (a) the nature of the credit derivative - its term, how it arose, the events or circumstances that would require the seller to perform under the credit derivative, and the current status of the payment/performance risk of the credit derivative; (b) the maximum potential amount of future payments (undiscounted) the seller could be required to make under the credit derivative; (c) the current fair value of the credit derivative; and (d) the nature of any recourse provisions under the credit derivative, and any assets held either as collateral or by third parties. A credit derivative is a derivative instrument (1) in which one or more of its underlyings are related to the credit risk of a specified entity (or a group of entities) or an index based on the credit risk of a group of entities and (2) that exposes the seller to potential loss from credit-risk-related events specified in the contract. Examples of credit derivatives within the scope of this paragraph include, but are not limited to, credit default swaps, credit spread options, and credit index products; also includes a hybrid instrument that has an embedded credit derivative (for example, but not limited to, a credit-linked note).

+ References+ Details

Tabular disclosure of the location and amount of gains and losses reported in the statement of financial performance, or when applicable, the statement of financial position. For example, (a) gains and losses recognized in the income statement on derivative instruments designated and qualifying as hedging instruments in fair value hedges and related hedged items designated and qualifying in fair value hedges and (b) gains and losses initially recognized in other comprehensive income on derivative instruments designated and qualifying as cash flow hedges.

+ References+ Details

Tabular disclosure of the location and fair value amounts of derivative instruments (and nonderivative instruments that are designated and qualify as hedging instruments) reported in the statement of financial position.

+ References+ Details

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

Assets and Liabilities Measured at Fair Value on Recurring Basis

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+ Details

Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2012

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


	Level 1					Level 2						Level 3						Netting Adjustments(4)						Total
(Millions of Dollars)	Con Edison			CECONY		Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY			Con Edison			CECONY
Derivative assets:
Commodity	$	-		$	-	$	43		$	8		$	33		$	10		$	(10	)	$	12		$	66		$	30
Transfer in(5)(6)		-			-		-			-			-			-			-			-			-			-
Transfer out(5)(6)		-			-		-			-			-			-			-			-			-			-
Commodity Total(1)	$	-		$	-	$	43		$	8		$	33		$	10		$	(10	)	$	12		$	66		$	30
Other assets	$	106		$	99	$	2		$	3		$	105		$	95		$	-		$	-		$	213		$	197
Transfer in(5)(6)		-			-		105			95			-			-			-			-			105			95
Transfer out(5)(6)		-			-		-			-			(105	)		(95	)		-			-			(105	)		(95	)
Other assets(3)	$	106		$	99	$	107		$	98		$	-		$	-		$	-		$	-		$	213		$	197
Total	$	106		$	99	$	150		$	106		$	33		$	10		$	(10	)	$	12		$	279		$	227
Derivative liabilities:
Commodity	$	5		$	3	$	114		$	62		$	47		$	9		$	(94	)	$	(35	)	$	72		$	39
Transfer in(5)(6)		9			9		13			9			2			-			-			-			24			18
Transfer out(5)(6)		(2	)		-		(11	)		(9	)		(11	)		(9	)		-			-			(24	)		(18	)
Commodity Total(1)	$	12		$	12	$	116		$	62		$	38		$	-		$	(94	)	$	(35	)	$	72		$	39
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	$	12		$	12	$	122		$	62		$	38		$	-		$	(94	)	$	(35	)	$	78		$	39

(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 O.

(2)	See Note O.

(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)

(2)	See Note O.

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

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

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

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

(7)	Transferred from Level 3 to Level 2 because of availability of observable market data due to decrease in the terms of certain contracts from beyond one year as of December 31, 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 December 31, 2012 (Millions of Dollars)			Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$	(5	)	Discounted Cash Flow	Forward prices(1)	$28-$82 per MWH
Electricity Wholesale Contract		(1	)	Discounted Cash Flow	Forward prices(2) New Jersey solar renewable energy credit (SREC)(2)	$29-$48 per MWH $90 per SREC
Standard Offer Capacity Agreements		(12	)	Discounted Cash Flow	Forward capacity prices(1) Forward price escalator(1) Present value factor(1)	$166 MW - day 0% - 3% 1.66%
Transmission Congestion Contracts / Financial Transmission Rights		13		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) Forward energy prices and zonal losses(1)	17.5% - 38% 8.5% - 31% $0.01 - $12
Total Con Edison —Commodity	$	(5	)
CECONY — Commodity
Transmission Congestion Contracts	$	10		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% 8.5%-31%

(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 Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value


	For the Year Ended December 31, 2012
				Total Gains/(Losses) – Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2012			Included in Earnings			Included in Regulatory Assets and Liabilities		Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3			Ending Balance as of December 31, 2012
Con Edison
Derivatives:
Commodity	$	(62	)	$	(112	)	$	16	$	22	$	-	$	-	$	122	$	9		$	(5	)
Interest rate contract		(8	)		(1	)		-		-		-		-		1		8	(2)		-
Other assets(1)		99			3			3		-		-		-		-		(105	)(2)		-
Total	$	29		$	(110	)	$	19	$	22	$	-	$	-	$	123	$	(88	)	$	(5	)
CECONY
Derivatives:
Commodity	$	(7	)	$	(32	)	$	8	$	18	$	-	$	-	$	14	$	9		$	10
Other assets(1)		90			3			2		-		-		-		-		(95	)(2)		-
Total	$	83		$	(29	)	$	10	$	18	$	-	$	-	$	14	$	(86	)	$	10

(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.


	For the Year Ended December 31, 2011
				Total Gains/(Losses) – Realized and Unrealized
(Millions of Dollars)	Beginning Balance as of January 1, 2011			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases		Issuances		Sales		Settlements		Transfer In/Out of Level 3		Ending Balance as of December 31, 2011
Con Edison
Derivatives:
Commodity	$	(88	)	$	(113	)	$	20		$	32	$	-	$	-	$	67	$	20	$	(62	)
Interest rate contract		(10	)		(3	)		2			-		-		-		3		-		(8	)
Other assets(1)		101			-			(2	)		-		-		-		-		-		99
Total	$	3		$	(116	)	$	20		$	32	$	-	$	-	$	70	$	20	$	29
CECONY
Derivatives:
Commodity	$	(26	)	$	(21	)	$	-		$	19	$	-	$	-	$	2	$	19	$	(7	)
Other assets(1)		92			-			(2	)		-		-		-		-		-		90
Total	$	66		$	(21	)	$	(2	)	$	19	$	-	$	-	$	2	$	19	$	83

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

Consolidated Statement of Capitalization - Long term Debt (Detail) (USD $)
In Millions, unless otherwise specified

12 Months Ended

Dec. 31, 2012

Dec. 31, 2011

Schedule of Capitalization, Long-term Debt [Line Items]

TOTAL DEBENTURE

$ 9,310

$ 9,210

TOTAL TRANSITION BONDS

TOTAL TAX-EXEMPT DEBT

1,130

Other long-term debt

319

321

Unamortized debt discount

(16)

(17)

TOTAL

10,768

10,673

Less: long-term debt due within one year

706

530

TOTAL LONG-TERM DEBT

10,062

10,143

TOTAL CAPITALIZATION

21,931

21,792

Debenture Series 2002A, 5.625% Due 2012 [Member]

Schedule of Capitalization, Long-term Debt [Line Items]

300

5.625%

Schedule of Capitalization, Long-term Debt [Line Items]

2012

Debenture Series 2002B, 4.875% Due 2013 [Member]

500

4.875%

Schedule of Capitalization, Long-term Debt [Line Items]

2013

Debenture Series 2003B, 3.85% Due 2013 [Member]

200

3.85%

Schedule of Capitalization, Long-term Debt [Line Items]

2013

Debenture Series 2004A, 4.70% Due 2014 [Member]

200

4.70%

Schedule of Capitalization, Long-term Debt [Line Items]

2014

Debenture Series 2009A, 5.55% Due 2014 [Member]

275

5.55%

Schedule of Capitalization, Long-term Debt [Line Items]

2014

Debenture Series 2005C, 5.375% Due 2015 [Member]

350

5.375%

Schedule of Capitalization, Long-term Debt [Line Items]

2015

Debenture Series 2006C, 5.50% Due 2016 [Member]

400

5.50%

Schedule of Capitalization, Long-term Debt [Line Items]

2016

Debenture Series 2006D, 5.30% Due 2016 [Member]

250

5.30%

Schedule of Capitalization, Long-term Debt [Line Items]

2016

Debenture Series 2008A, 5.85% Due 2018 [Member]

600

5.85%

Schedule of Capitalization, Long-term Debt [Line Items]

2018

Debenture Series 2008C, 7.125% Due 2018 [Member]

600

7.125%

Schedule of Capitalization, Long-term Debt [Line Items]

2018

Debenture Series 2009B, 6.65% Due 2019 [Member]

475

6.65%

Schedule of Capitalization, Long-term Debt [Line Items]

2019

Debenture Series 2010A, 4.45% Due 2020 [Member]

350

4.45%

Schedule of Capitalization, Long-term Debt [Line Items]

2020

Debenture Series 2003A, 5.875% Due 2033 [Member]

175

5.875%

Schedule of Capitalization, Long-term Debt [Line Items]

2033

Debenture Series 2003C, 5.10% Due 2033 [Member]

200

5.10%

Schedule of Capitalization, Long-term Debt [Line Items]

2033

Debenture Series 2004B, 5.70% Due 2034 [Member]

200

5.70%

Schedule of Capitalization, Long-term Debt [Line Items]

2034

Debenture Series 2005A, 5.30% Due 2035 [Member]

350

5.30%

Schedule of Capitalization, Long-term Debt [Line Items]

2035

Debenture Series 2005B, 5.25% Due 2035 [Member]

125

5.25%

Schedule of Capitalization, Long-term Debt [Line Items]

2035

Debenture Series 2006A, 5.85% Due 2036 [Member]

400

5.85%

Schedule of Capitalization, Long-term Debt [Line Items]

2036

Debenture Series 2006B, 6.20% Due 2036 [Member]

400

6.20%

Schedule of Capitalization, Long-term Debt [Line Items]

2036

Debenture Series 2006E, 5.70% Due 2036 [Member]

250

5.70%

Schedule of Capitalization, Long-term Debt [Line Items]

2036

Debenture Series 2007A, 6.30% Due 2037 [Member]

525

6.30%

Schedule of Capitalization, Long-term Debt [Line Items]

2037

Debenture Series 2008B, 6.75% Due 2038 [Member]

600

6.75%

Schedule of Capitalization, Long-term Debt [Line Items]

2038

Debenture Series 2009C, 5.50% Due 2039 [Member]

600

5.50%

Schedule of Capitalization, Long-term Debt [Line Items]

2039

Debenture Series 2010B, 5.70% Due 2040 [Member]

350

5.70%

Schedule of Capitalization, Long-term Debt [Line Items]

2040

Debenture Series 2012A, 4.20% Due 2042 [Member]

400

4.20%

Schedule of Capitalization, Long-term Debt [Line Items]

2042

Tax Exempt Debt Series 2004B-1, 0.32% Due 2032 [Member]

127

^[1]

127

^[1]

0.32%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2032

^[1]

Tax-Exempt Debt Series 1999A, 0.27% Due 2034 [Member]

293

^[1]

293

^[1]

0.27%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2034

^[1]

Tax Exempt Debt Series 2004B-2, 0.28% Due 2035 [Member]

^[1]

0.28%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2035

^[1]

Tax-Exempt Debt Series 2001B, 0.23% Due 2036 [Member]

^[1]

0.23%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2036

^[1]

Tax-Exempt Debt Series 2010A, 0.13% Due 2036 [Member]

225

^[1]

225

^[1]

0.13%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2036

^[1]

Tax-Exempt Debt Series 2004A, 0.23% Due 2039 [Member]

^[1]

0.23%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2039

^[1]

Tax-Exempt Debt Series 2004C, 0.13% Due 2039 [Member]

^[1]

0.13%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2039

^[1]

Tax-Exempt Debt Series 2005A, 0.11% Due 2039 [Member]

126

^[1]

126

^[1]

0.11%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2039

^[1]

Debenture Series 2005A, 5.30% Due 2015 [Member]

5.30%

Schedule of Capitalization, Long-term Debt [Line Items]

2015

Debenture Series 2010A, 2.50% Due 2015 [Member]

2.50%

Schedule of Capitalization, Long-term Debt [Line Items]

2015

Debenture Series 2006A, 5.45% Due 2016 [Member]

5.45%

Schedule of Capitalization, Long-term Debt [Line Items]

2016

Debenture Series 2008A, 6.15% Due 2018 [Member]

6.15%

Schedule of Capitalization, Long-term Debt [Line Items]

2018

Debenture Series 2009A, 4.96% Due 2019 [Member]

4.96%

Schedule of Capitalization, Long-term Debt [Line Items]

2019

Debenture Series 1997F, 6.50% Due 2027 [Member]

6.50%

Schedule of Capitalization, Long-term Debt [Line Items]

2027

Debenture Series 2009B, 6.00% Due 2039 [Member]

6.00%

Schedule of Capitalization, Long-term Debt [Line Items]

2039

Debenture Series 2010B, 5.50% Due 2040 [Member]

115

5.50%

Schedule of Capitalization, Long-term Debt [Line Items]

2040

Debenture Series 2004-1, 5.22% Due 2019 [Member]

^[2]

5.22%

^[2]

Schedule of Capitalization, Long-term Debt [Line Items]

2019

^[2]

Debenture Series 1995, 0.21% Due 2015 [Member]

^[1],[3]

0.21%

^[1],[3]

Schedule of Capitalization, Long-term Debt [Line Items]

2015

^[1],[3]

CECONY [Member]

TOTAL DEBENTURE

8,775

8,675

TOTAL TAX-EXEMPT DEBT

1,086

Unamortized debt discount

(16)

TOTAL

9,845

9,745

Less: long-term debt due within one year

700

525

TOTAL LONG-TERM DEBT

9,145

9,220

TOTAL CAPITALIZATION

19,697

19,651

CECONY [Member] | Debenture Series 2002A, 5.625% Due 2012 [Member]

Schedule of Capitalization, Long-term Debt [Line Items]

300

5.625%

Schedule of Capitalization, Long-term Debt [Line Items]

2012

CECONY [Member] | Debenture Series 2002B, 4.875% Due 2013 [Member]

500

4.875%

Schedule of Capitalization, Long-term Debt [Line Items]

2013

CECONY [Member] | Debenture Series 2003B, 3.85% Due 2013 [Member]

200

3.85%

Schedule of Capitalization, Long-term Debt [Line Items]

2013

CECONY [Member] | Debenture Series 2004A, 4.70% Due 2014 [Member]

200

4.70%

Schedule of Capitalization, Long-term Debt [Line Items]

2014

CECONY [Member] | Debenture Series 2009A, 5.55% Due 2014 [Member]

275

5.55%

Schedule of Capitalization, Long-term Debt [Line Items]

2014

CECONY [Member] | Debenture Series 2005C, 5.375% Due 2015 [Member]

350

5.375%

Schedule of Capitalization, Long-term Debt [Line Items]

2015

CECONY [Member] | Debenture Series 2006C, 5.50% Due 2016 [Member]

400

5.50%

Schedule of Capitalization, Long-term Debt [Line Items]

2016

CECONY [Member] | Debenture Series 2006D, 5.30% Due 2016 [Member]

250

5.30%

Schedule of Capitalization, Long-term Debt [Line Items]

2016

CECONY [Member] | Debenture Series 2008A, 5.85% Due 2018 [Member]

600

5.85%

Schedule of Capitalization, Long-term Debt [Line Items]

2018

CECONY [Member] | Debenture Series 2008C, 7.125% Due 2018 [Member]

600

7.125%

Schedule of Capitalization, Long-term Debt [Line Items]

2018

CECONY [Member] | Debenture Series 2009B, 6.65% Due 2019 [Member]

475

6.65%

Schedule of Capitalization, Long-term Debt [Line Items]

2019

CECONY [Member] | Debenture Series 2010A, 4.45% Due 2020 [Member]

350

4.45%

Schedule of Capitalization, Long-term Debt [Line Items]

2020

CECONY [Member] | Debenture Series 2003A, 5.875% Due 2033 [Member]

175

5.875%

Schedule of Capitalization, Long-term Debt [Line Items]

2033

CECONY [Member] | Debenture Series 2003C, 5.10% Due 2033 [Member]

200

5.10%

Schedule of Capitalization, Long-term Debt [Line Items]

2033

CECONY [Member] | Debenture Series 2004B, 5.70% Due 2034 [Member]

200

5.70%

Schedule of Capitalization, Long-term Debt [Line Items]

2034

CECONY [Member] | Debenture Series 2005A, 5.30% Due 2035 [Member]

350

5.30%

Schedule of Capitalization, Long-term Debt [Line Items]

2035

CECONY [Member] | Debenture Series 2005B, 5.25% Due 2035 [Member]

125

5.25%

Schedule of Capitalization, Long-term Debt [Line Items]

2035

CECONY [Member] | Debenture Series 2006A, 5.85% Due 2036 [Member]

400

5.85%

Schedule of Capitalization, Long-term Debt [Line Items]

2036

CECONY [Member] | Debenture Series 2006B, 6.20% Due 2036 [Member]

400

6.20%

Schedule of Capitalization, Long-term Debt [Line Items]

2036

CECONY [Member] | Debenture Series 2006E, 5.70% Due 2036 [Member]

250

5.70%

Schedule of Capitalization, Long-term Debt [Line Items]

2036

CECONY [Member] | Debenture Series 2007A, 6.30% Due 2037 [Member]

525

6.30%

Schedule of Capitalization, Long-term Debt [Line Items]

2037

CECONY [Member] | Debenture Series 2008B, 6.75% Due 2038 [Member]

600

6.75%

Schedule of Capitalization, Long-term Debt [Line Items]

2038

CECONY [Member] | Debenture Series 2009C, 5.50% Due 2039 [Member]

600

5.50%

Schedule of Capitalization, Long-term Debt [Line Items]

2039

CECONY [Member] | Debenture Series 2010B, 5.70% Due 2040 [Member]

350

5.70%

Schedule of Capitalization, Long-term Debt [Line Items]

2040

CECONY [Member] | Debenture Series 2012A, 4.20% Due 2042 [Member]

400

4.20%

Schedule of Capitalization, Long-term Debt [Line Items]

2042

CECONY [Member] | Tax Exempt Debt Series 2004B-1, 0.32% Due 2032 [Member]

127

^[1]

127

^[1]

0.32%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2032

^[1]

CECONY [Member] | Tax-Exempt Debt Series 1999A, 0.27% Due 2034 [Member]

293

^[1]

293

^[1]

0.27%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2034

^[1]

CECONY [Member] | Tax Exempt Debt Series 2004B-2, 0.28% Due 2035 [Member]

^[1]

0.28%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2035

^[1]

CECONY [Member] | Tax-Exempt Debt Series 2001B, 0.23% Due 2036 [Member]

^[1]

0.23%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2036

^[1]

CECONY [Member] | Tax-Exempt Debt Series 2010A, 0.13% Due 2036 [Member]

225

^[1]

225

^[1]

0.13%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2036

^[1]

CECONY [Member] | Tax-Exempt Debt Series 2004A, 0.23% Due 2039 [Member]

^[1]

0.23%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2039

^[1]

CECONY [Member] | Tax-Exempt Debt Series 2004C, 0.13% Due 2039 [Member]

^[1]

0.13%

^[1]

Schedule of Capitalization, Long-term Debt [Line Items]

2039

^[1]

CECONY [Member] | Tax-Exempt Debt Series 2005A, 0.11% Due 2039 [Member]

$ 126

^[1]

$ 126

^[1]

0.11%

^[1]

2039

^[1]

[1]	Rates reset weekly or by auction held every 35 days; December 31, 2012 rates shown.
[2]	The final date to pay the entire remaining unpaid principal balance, if any, of all outstanding bonds is May 17, 2021.
[3]	Issued for O&R pollution control financing.

Summary of Significant Accounting Policies - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Summary Of Significant Accounting Policies [Line Items]
Annual aggregate depreciation allowance	$ 935
Investment gains and losses recognized, time period, years	15
Investment gains and losses recognized, time period, years	10
Difference between fair value and expected Market Related Value of plan assets	20.00%
Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	3 years
Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	30 years
CECONY [Member]
Summary Of Significant Accounting Policies [Line Items]
AFDC rates	6.50%	6.90%	5.30%
Average depreciation rate	3.10%	3.10%	3.10%
Annual aggregate depreciation allowance	$ 888
CECONY [Member] \| Electric [Member] \| Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	5 years
CECONY [Member] \| Electric [Member] \| Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	80 years
CECONY [Member] \| Gas Transmission [Member] \| Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	5 years
CECONY [Member] \| Gas Transmission [Member] \| Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	85 years
CECONY [Member] \| Steam Plant [Member] \| Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	5 years
CECONY [Member] \| Steam Plant [Member] \| Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	70 years
CECONY [Member] \| General [Member] \| Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	5 years
CECONY [Member] \| General [Member] \| Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	50 years
O & R [Member]
Summary Of Significant Accounting Policies [Line Items]
AFDC rates	7.00%	6.60%	5.80%
Average depreciation rate	2.90%	2.80%	2.80%
O & R [Member] \| Electric [Member] \| Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	5 years
O & R [Member] \| Electric [Member] \| Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	75 years
O & R [Member] \| Gas Transmission [Member] \| Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	5 years
O & R [Member] \| Gas Transmission [Member] \| Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	75 years
O & R [Member] \| General [Member] \| Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	5 years
O & R [Member] \| General [Member] \| Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives,(years)	50 years

Summary of Significant Accounting Policies - Capitalized Cost of Utility Plant (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 2,302	$ 1,944
Held for future use	72	74
Construction work in progress	1,027	1,241
Net Utility Plant	26,301	24,965
Electric [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Generation	434	400
Electric Transmission [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	2,698	2,654
Electric Distribution [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	14,658	13,805
Gas Transmission [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Gas	4,170	3,858
Steam Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,674	1,651
General [Member]
Public Utility, Property, Plant and Equipment [Line Items]
General	1,567	1,282
CECONY [Member]
Public Utility, Property, Plant and Equipment [Line Items]
General	2,126	1,785
Held for future use	62	62
Construction work in progress	947	1,165
Net Utility Plant	24,739	23,496
CECONY [Member] \| Electric [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Generation	434	400
CECONY [Member] \| Electric Transmission [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	2,518	2,476
CECONY [Member] \| Electric Distribution [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	13,930	13,125
CECONY [Member] \| Gas Transmission [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Gas	3,735	3,455
CECONY [Member] \| Steam Plant [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,674	1,651
CECONY [Member] \| General [Member]
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 1,439	$ 1,162

Summary of Significant Accounting Policies - Research and Development Costs (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Accounting Policies [Line Items]
Research and Development Costs	$ 21	$ 23	$ 23
CECONY [Member]
Accounting Policies [Line Items]
Research and Development Costs	$ 19	$ 21	$ 21

The aggregate costs incurred (1) in a planned search or critical investigation aimed at discovery of new knowledge with the hope that such knowledge will be useful in developing a new product or service, a new process or technique, or in bringing about a significant improvement to an existing product or process; or (2) to translate research findings or other knowledge into a plan or design for a new product or process or for a significant improvement to an existing product or process whether intended for sale or the entity's use, during the reporting period charged to research and development projects, including the costs of developing computer software up to the point in time of achieving technological feasibility, and costs allocated in accounting for a business combination to in-process projects deemed to have no alternative future use.

+ References+ Details

Summary of Significant Accounting Policies - Earnings Per Common Share (Detail) (USD $) In Millions, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Earnings Per Share [Line Items]
Net income for common stock	$ 1,138	$ 1,051	$ 992
Weighted average common shares outstanding - Basic	292.9	292.6	284.3
Add: Incremental shares attributable to effect of potentially dilutive securities	1.6	1.8	1.6
Adjusted weighted average common shares outstanding - Diluted	294.5	294.4	285.9
Net income for common stock per common share - basic	$ 3.88	$ 3.59	$ 3.49
Net income for common stock per common share - diluted	$ 3.86	$ 3.57	$ 3.47

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 128

-Paragraph 36, 37, 38

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Emerging Issues Task Force (EITF)

-Number 07-4

-Paragraph 4

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 50

-Paragraph 1

-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 225

-SubTopic 10

-Section S99

-Paragraph 2

-Subparagraph (SX 210.5-03.21)

-URI http://asc.fasb.org/extlink&oid=6880815&loc=d3e20235-122688

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 45

-Paragraph 2

-URI http://asc.fasb.org/extlink&oid=7655603&loc=d3e1252-109256

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 04

-Paragraph 18

-Article 7

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 03

-Paragraph 20

-Article 5

Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 04

-Paragraph 21

-Article 9

Reference 9: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 55

-Paragraph 52

-URI http://asc.fasb.org/extlink&oid=16381557&loc=d3e4984-109258

Reference 10: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 944

-SubTopic 225

-Section S99

-Paragraph 1

-Subparagraph (SX 210.7-04.19)

-URI http://asc.fasb.org/extlink&oid=6879464&loc=d3e573970-122913

Reference 11: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 942

-SubTopic 225

-Section S99

-Paragraph 1

-Subparagraph (SX 210.9-04.23)

-URI http://asc.fasb.org/extlink&oid=6879574&loc=d3e536633-122882

+ Details

The amount of net income (loss) for the period available to each share of common stock or common unit outstanding during the reporting period and to each share or unit that would have been outstanding assuming the issuance of common shares or units for all dilutive potential common shares or units outstanding during the reporting period.

+ References+ Details

Additional shares included in the calculation of diluted EPS as a result of the potentially dilutive effect of contingently issuable shares. Contingently issuable shares are those shares that are issuable for little or no cash contingent on certain conditions being met.

+ References+ Details

The average number of shares or units issued and outstanding that are used in calculating diluted EPS or earnings per unit (EPU), determined based on the timing of issuance of shares or units in the period.

+ References+ Details

Number of [basic] shares or units, after adjustment for contingently issuable shares or units and other shares or units not deemed outstanding, determined by relating the portion of time within a reporting period that common shares or units have been outstanding to the total time in that period.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 50

-Paragraph 1

-Subparagraph (a)

-URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Emerging Issues Task Force (EITF)

-Number 07-4

-Paragraph 4

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 128

-Paragraph 171

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 128

-Paragraph 40

-Subparagraph a

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 260

-SubTopic 10

-Section 45

-Paragraph 10

-URI http://asc.fasb.org/extlink&oid=7655603&loc=d3e1448-109256

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 128

-Paragraph 8

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Glossary Weighted-Average Number of Common Shares Outstanding

-URI http://asc.fasb.org/extlink&oid=6528421

+ Details

Regulatory Matters - Cecony - Electric - Additional Information (Detail) (USD $)	12 Months Ended		12 Months Ended			12 Months Ended						12 Months Ended									12 Months Ended									12 Months Ended														12 Months Ended															12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012 CECONY - Electric [Member]	Dec. 31, 2011 CECONY - Electric [Member]	Dec. 31, 2010 CECONY - Electric [Member]	Dec. 31, 2012 CECONY - Electric [Member] T&D [Member]	Dec. 31, 2012 CECONY - Electric [Member] Other [Member]	Dec. 31, 2012 CECONY - Electric [Member] Effective April 2009 [Member]	Dec. 31, 2011 CECONY - Electric [Member] Effective April 2009 [Member]	Dec. 31, 2009 CECONY - Electric [Member] Effective April 2009 [Member]	Dec. 31, 2010 CECONY - Electric [Member] Effective April 2009 [Member]	Dec. 31, 2012 CECONY - Electric [Member] Effective April 2009 [Member] Revenue decoupling mechanism [Member]	Dec. 31, 2012 CECONY - Electric [Member] November 2009 Joint Proposal [Member]	Dec. 31, 2012 CECONY - Electric [Member] Sale of transmission rights [Member]	Dec. 31, 2011 CECONY - Electric [Member] Sale of transmission rights [Member]	Dec. 31, 2010 CECONY - Electric [Member] Sale of transmission rights [Member]	Mar. 31, 2012 CECONY - Electric [Member] March 2013 [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2013 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2013 [Member] 90% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2013 [Member] 60% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2013 [Member] T&D [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2013 [Member] Other [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2013 [Member] ERP [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2013 [Member] November 2009 Joint Proposal [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2010 [Member] Effective April 2009 [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2011 [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2011 [Member] 50% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2011 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2011 [Member] 90% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2011 [Member] T&D [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2011 [Member] Other [Member]	Mar. 31, 2011 CECONY - Electric [Member] March 2011 [Member] ERP [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2011 [Member] Effective April 2009 [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2011 [Member] November 2009 Joint Proposal [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2008 rate order [Member] Effective April 2009 [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2009 [Member] Effective April 2009 [Member]	Dec. 31, 2012 CECONY - Electric [Member] April 2010 [Member] November 2009 Joint Proposal [Member]	Dec. 31, 2012 CECONY - Electric [Member] April 2011 [Member] November 2009 Joint Proposal [Member]	Dec. 31, 2012 CECONY - Electric [Member] April 2012 [Member] November 2009 Joint Proposal [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2012 [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2012 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2012 [Member] 90% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2012 [Member] 60% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2012 [Member] T&D [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2012 [Member] Other [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2012 [Member] ERP [Member]	Dec. 31, 2012 CECONY - Electric [Member] March 2012 [Member] November 2009 Joint Proposal [Member]	Dec. 31, 2012 CECONY - Electric [Member] February 2010 [Member]	Dec. 31, 2012 CECONY - Electric [Member] January 2014 [Member]	Dec. 31, 2012 CECONY - Electric [Member] January 2015 [Member]	Dec. 31, 2012 CECONY - Electric [Member] January 2016 [Member]	Dec. 31, 2012 CECONY - Electric [Member] Maximum [Member]	Dec. 31, 2012 CECONY - Electric [Member] Maximum [Member] March 2013 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Maximum [Member] March 2013 [Member] 60% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Maximum [Member] March 2011 [Member] 50% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Maximum [Member] March 2011 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Maximum [Member] March 2012 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Maximum [Member] March 2012 [Member] 60% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2013 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2013 [Member] 90% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2013 [Member] 60% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2011 [Member] 50% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2011 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2011 [Member] 90% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2012 [Member] 75% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2012 [Member] 90% of earnings [Member]	Dec. 31, 2012 CECONY - Electric [Member] Minimum [Member] March 2012 [Member] 60% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Revenue from electric	$ 249,000,000																								$ 254,000,000								$ 249,000,000
Regulatory liability	14,000,000									24,000,000
Regulatory liability recognition after tax charge										14,000,000
Credit to customer								36,000,000
Electric base rate increase								523,000,000																													420,000,000	420,000,000	287,000,000										375,000,000	195,000,000	270,000,000
Return of common equity			10.85%					10.00%					10.15%																																				10.35%
Common equity ratio			50.00%					48.00%					48.00%																																				50.00%			50.00%
Revenue requirements								60,000,000																	60,000,000
Increased revenues												122,000,000
Decrease in annual revenue								150,000,000																											120,000,000
Revenues difference between actual and rate year, recoverable from customers								120,000,000
Accrued revenues								7,000,000						45,000,000	26,000,000	9,000,000
Deferred expenses								36,400,000
Surcharge collected from customers								198,000,000									134,000,000							134,000,000
Potential operational penalties								152,000,000
Potential refund to customers																									254,000,000											237,000,000
Austerity plan costs																									47,000,000
Weighted average cost of capital													7.76%
Operations and maintenance expenses																								27,000,000										13,000,000													20,000,000
Long term debt cost													5.65%
Average base rate																								16,826,000,000										14,887,000,000													15,987,000,000
Deferred regulatory liabilities																					15,414	1,650	115			8.0				13,818	1,487									0.1				14,742	1,565	25
Capital expenditures						2,300,000,000	402,000,000																							1,200,000,000	220,000,000	125,000,000
Percentage of revenue allocated to customers																		75.00%	90.00%	60.00%							50.00%	75.00%	90.00%												75.00%	90.00%	60.00%
Percentage of revenue requirement earnings																																																					13.149%	12.149%	12.149%	13.149%	13.149%	12.149%		12.15%	13.15%	10.65%	11.15%	12.15%	13.15%	12.15%	13.15%	10.65%
Percentage of share to reduce regulatory assets			50.00%
Maximum impact on return on common equity and deferral of facility relocation expenses			Not more than a 10 basis point
Deferred net regulatory asset	126,000,000	173,000,000			264,000,000
Deferred net regulatory liability	2,061,000,000	1,971,000,000		39,000,000
Difference in property taxes																																																				80.00%							20.00%
Deferred revenues								59,000,000	90,000,000		124,000,000
Potential operations penalties								152,000,000
System reliability penalty									5,000,000
Potential refund from customers																																																$ 249,000,000

Regulatory Matters - Schedule of Regulatory Liability Revenue Requirement Impact (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012
March 2011 [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	$ 8.0
March 2011 [Member] \| T&D [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	13,818
March 2011 [Member] \| Other [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	1,487
March 2011 [Member] \| Production [Member] \| CECONY - Steam [Member]
Regulatory Assets [Line Items]
ERP	415
March 2011 [Member] \| Distribution [Member] \| CECONY - Steam [Member]
Regulatory Assets [Line Items]
ERP	521
March 2012 [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	0.1
March 2012 [Member] \| T&D [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	14,742
March 2012 [Member] \| Other [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	1,565
March 2012 [Member] \| ERP [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	25
March 2012 [Member] \| Production [Member] \| CECONY - Steam [Member]
Regulatory Assets [Line Items]
ERP	426
March 2012 [Member] \| Distribution [Member] \| CECONY - Steam [Member]
Regulatory Assets [Line Items]
ERP	534
March 2013 [Member] \| T&D [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	15,414
March 2013 [Member] \| Other [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	1,650
March 2013 [Member] \| ERP [Member] \| CECONY - Electric [Member]
Regulatory Assets [Line Items]
ERP	115
March 2013 [Member] \| Production [Member] \| CECONY - Steam [Member]
Regulatory Assets [Line Items]
ERP	433
March 2013 [Member] \| Distribution [Member] \| CECONY - Steam [Member]
Regulatory Assets [Line Items]
ERP	$ 543

Regulatory Matters - Orange and Rockland Utilities, Inc. - Electric - Additional Information (Detail) (O & R [Member], USD $)	1 Months Ended	12 Months Ended
	May 31, 2010	Dec. 31, 2012	Dec. 31, 2012 July 2008 [Member]	Dec. 31, 2011 July 2008 [Member]	Dec. 31, 2010 July 2008 [Member]	Dec. 31, 2009 July 2008 [Member]	Mar. 31, 2007 March 2007 [Member]	Dec. 31, 2012 July 2008 [Member]	Dec. 31, 2012 July 2009 [Member]	Dec. 31, 2012 July 2010 [Member]	Dec. 31, 2012 July 2011[Member]	Dec. 31, 2012 June 30, 2013 [Member]	Dec. 31, 2012 June 30, 2014 [Member]	Dec. 31, 2012 June 30, 2015 [Member]	Dec. 31, 2012 July 2012 [Member]	Dec. 31, 2012 July 2013 [Member]	Dec. 31, 2012 July 2014 [Member]	Dec. 31, 2012 Maximum [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Electricity base rate increases	$ 9.8						$ 6.4	$ 15.6	$ 15.6	$ 5.7	$ 26.6				$ 19.4	$ 8.8	$ 15.2
Collection of additional electric cost										9,900,000
Annual return on common equity	10.30%		9.40%	9.40%			9.75%				9.20%	9.40%	9.50%	9.60%
Actual earnings on equity,percentage			10.20%
Average common equity ratio subject to a 50 percent maximum			50.00%
Recognition of deferred expenses				300,000		3,000,000
Recognition of deferred revenue					700,000
Company deferred revenue				7,000,000	12,000,000	8,000,000
Annual inflation rate				4.00%
Potential negative earnings adjustments			3,000,000
Reduction in company revenue					1,000,000
Accrued revenue				3,300,000	5,100,000	12,500,000
Electric base rate increase	9.8						6.4	15.6	15.6	5.7	26.6				19.4	8.8	15.2
Weighted average cost of capital											7.22%	7.61%	7.65%	7.48%
Annual return on common equity	10.30%		9.40%	9.40%			9.75%				9.20%	9.40%	9.50%	9.60%
Austerity measures											825,000
Cost of long-term debt,percentage											5.50%
Common equity ratio	50.00%						46.50%				48.00%	48.00%	48.00%	48.00%				50.00%
Average net utility plant rates											718	678	704	753
Potential operational penalties		3,000,000									3,000,000
Surcharge payment																	2,100,000
Increase rate															15,200,000	15,200,000	13,100,000
Cost of long term debt												6.07%	6.07%	5.64%
Average base rate												$ 671	$ 708	$ 759
Percentage of revenue allocated to customers												50.00%	75.00%	90.00%
Common equity basis points												80	180	280

Regulatory Matters - Cecony - Gas - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
Schedule Of Regulatory Assets And Liabilities [Line Items]
Deferred regulatory liabilities	$ 9,644,000,000	$ 8,604,000,000
Deferred net regulatory assets	126,000,000	173,000,000
Deferred net regulatory liabilities	2,061,000,000	1,971,000,000
CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Increase in annual funding for new energy efficiency program	14,000,000
Accrued revenues			24,000,000	25,000,000	17,000,000
Return on common equity	9.60%	10.70%
Percentage of share to reduce regulatory assets	50.00%
Common equity basis points	10
Deferred net regulatory assets	46,000,000		67,000,000
Deferred net regulatory liabilities		300,000
Amount of revenues retained	58,000,000
Percentage of revenue reserve	25.00%
Accrual of regulatory asset	33,000,000
Percentage of difference between targeted and least revenue reserve	80.00%
Potential operational penalties	12,600,000
Potential refund from customers	32,000,000
CECONY - Gas [Member] \| Gas Distribution Revenues [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Deferred net regulatory assets			14,000,000
Deferred net regulatory liabilities	22,000,000	20,000,000
CECONY - Gas [Member] \| Maximum [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Common equity ratio	50.00%
Difference in property taxes	80.00%
CECONY - Gas [Member] \| Minimum [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Difference in property taxes	20.00%
CECONY - Gas [Member] \| September 2007 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Amount of revenues retained	57,000,000	70,000,000	40,000,000
CECONY - Gas [Member] \| September 2010 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Weighted average cost of capital, percentage	7.46%
October One Two Thousand Seven [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Gas base rate increase	84,600,000
Increase in annual gas rate	67,500,000
Gas base rate increase	84,600,000
October One Two Thousand Eight [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Gas base rate increase	32,700,000
Increase in annual gas rate	67,500,000
Gas base rate increase	32,700,000
October One Two Thousand Nine [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Gas base rate increase	42,700,000
Increase in annual gas rate	67,500,000
Gas base rate increase	42,700,000
September 2010 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Decrease in earnings	6,000,000
September 2009 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Decrease in earnings	0
September 2013 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Decrease in earnings	9,000,000
Reductions in costs	2,000,000
Average base rate	3,434,000,000
Deferred regulatory liabilities	3,346,000,000
September 2011 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Reductions in costs	6,000,000
Average base rate	3,027,000,000
Deferred regulatory liabilities	2,934,000,000
September 2011 [Member] \| CECONY - Gas [Member] \| 60% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue allocated to customers	60.00%
September 2011 [Member] \| CECONY - Gas [Member] \| 75% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue allocated to customers	75.00%
September 2011 [Member] \| CECONY - Gas [Member] \| 90% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue allocated to customers	90.00%
September 2011 [Member] \| CECONY - Gas [Member] \| Maximum [Member] \| 60% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	11.59%
September 2011 [Member] \| CECONY - Gas [Member] \| Maximum [Member] \| 75% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	12.59%
September 2011 [Member] \| CECONY - Gas [Member] \| Maximum [Member] \| 90% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	10.35%
September 2011 [Member] \| CECONY - Gas [Member] \| Minimum [Member] \| 60% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	10.35%
September 2011 [Member] \| CECONY - Gas [Member] \| Minimum [Member] \| 75% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	11.60%
September 2011 [Member] \| CECONY - Gas [Member] \| Minimum [Member] \| 90% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	12.60%
September 2012 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Reductions in costs	4,000,000
Average base rate	3,245,000,000
Deferred regulatory liabilities	3,148,000,000
May 2010 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Cost of long term debt	5.57%
Common equity ratio	48.00%
September 2012, 2013 [Member] \| CECONY - Gas [Member] \| 60% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue allocated to customers	60.00%
September 2012, 2013 [Member] \| CECONY - Gas [Member] \| 75% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue allocated to customers	75.00%
September 2012, 2013 [Member] \| CECONY - Gas [Member] \| 90% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue allocated to customers	90.00%
September 2012, 2013 [Member] \| CECONY - Gas [Member] \| Maximum [Member] \| 60% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	11.59%
September 2012, 2013 [Member] \| CECONY - Gas [Member] \| Maximum [Member] \| 75% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	12.59%
September 2012, 2013 [Member] \| CECONY - Gas [Member] \| Maximum [Member] \| 90% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	12.60%
September 2012, 2013 [Member] \| CECONY - Gas [Member] \| Minimum [Member] \| 60% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	10.10%
September 2012, 2013 [Member] \| CECONY - Gas [Member] \| Minimum [Member] \| 75% of earnings [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Percentage of revenue requirement earnings	11.60%
January 2014 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Return on common equity	10.35%
Common equity ratio	50.00%
Gas base rate increase	25,000,000
January 2015 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Return on common equity	10.85%
Common equity ratio	50.00%
Gas base rate increase	55,000,000
January 2016 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Gas base rate increase	63,000,000
October 2010 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Gas base rate increase	47,100,000
Gas base rate increase	47,100,000
October 2011 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Gas base rate increase	47,900,000
Gas base rate increase	47,900,000
October 2012 [Member] \| CECONY - Gas [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Gas base rate increase	46,700,000
Gas base rate increase	$ 46,700,000

Regulatory Matters - Orange and Rockland Utilities, Inc. - Gas - Additional Information (Detail) (O & R [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule Of Regulatory Assets And Liabilities [Line Items]
Return on common equity	10.40%
Recognition of deferred expenses	$ 0.7	$ 2.9	$ 3.1
Deferred Revenue			1.5
Deferred expense	0.7	1.0
Annual inflation rate	4.00%
Accrued revenue	4.7	2.8	0.8
November 2009 Joint Proposal [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Increase rate	9.0
November Two Thousand Ten [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Increase rate	9.0
November Two Thousand Eleven [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Increase rate	4.6
Surcharge payment	4.3
Minimum [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Return on common equity	11.40%
Maximum [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Actual average common equity ratio	50.00%
Annual negative earnings adjustments	$ 1.4

Regulatory Matters - Cecony - Steam - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008	Dec. 31, 2011
Schedule Of Regulatory Assets And Liabilities [Line Items]
Regulatory liability	$ 183,000,000				$ 118,000,000
Deferred net regulatory liabilities	2,061,000,000				1,971,000,000
CECONY - Steam [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Steam rate increase	43,700,000
Return on common equity	9.30%
Difference between actual costs and costs reflected in rates	90.00%
Decreased expenses		14,900,000	14,400,000
Increased expenses				3,100,000
Non-cash increase in steam revenues	20,300,000
Deferred net regulatory liabilities	200,000				300,000
Potential refund from customers	6,000,000
Potential operational penalties	1,000,000
Return on common equity	9.30%
CECONY - Steam [Member] \| September Two Thousand And Nine [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Regulatory liability	0
CECONY - Steam [Member] \| September 2010 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Regulatory liability	4,000,000
CECONY - Steam [Member] \| October 2010 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Increase rate	49,500,000
CECONY - Steam [Member] \| October 2011 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Increase rate	49,500,000
CECONY - Steam [Member] \| October 2012 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Increase rate	17,800,000
CECONY - Steam [Member] \| September 2013 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Surcharge collected from customers	31.7
Reduction of cost	1,500,000
Average base rate	1,613,000,000
CECONY - Steam [Member] \| September 2011 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Reduction of cost	4,500,000
Average base rate	1,589,000,000
CECONY - Steam [Member] \| September 2012 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Reduction of cost	3,000,000
Average base rate	1,603,000,000
CECONY - Steam [Member] \| January 2014 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Return on common equity	10.35%
Gas base rate increase	5,000,000
Common equity ratio	50.00%
Gas base rate increase	5,000,000
Return on common equity	10.35%
CECONY - Steam [Member] \| January 2015 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Return on common equity	10.85%
Gas base rate increase	22,000,000
Gas base rate increase	22,000,000
Return on common equity	10.85%
CECONY - Steam [Member] \| January 2016 [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Gas base rate increase	18,000,000
Common equity ratio	50.00%
Gas base rate increase	18,000,000
CECONY - Steam [Member] \| Maximum [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Return on common equity	10.10%
Average common equity ratio	50.00%
Potential negative earnings adjustments	1,000,000
Return on common equity	10.10%
CECONY - Steam [Member] \| Minimum [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Potential negative earnings adjustments	$ 950,000

Regulatory Matters - Other Regulatory Matters - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Schedule Of Regulatory Assets And Liabilities [Line Items]
Revenue from electric	$ 249,000,000
Revenue from gas	32,000,000
Revenue from steam service	6,000,000
Potential refund from customers	1,103
Overcharges of construction expenditures	208,000,000
Regulatory liability	14,000,000
Regulatory liabilities	183,000,000	118,000,000
Storm Damage [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Number of customers Interrupted electric distribution service	1,400,000
Net unbilled revenue deferrals [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Regulatory liabilities	136,000,000
CECONY [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Response and restoration costs	363,000,000
Capital expenditure	104,000,000
Regulatory liabilities	145,000,000	79,000,000
O & R [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Response and restoration costs	98,000,000
Capital expenditure	$ 14,000,000

Regulatory Matters - Regulatory Assets and Liabilities (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Regulatory Assets [Line Items]
Regulatory assets - long-term	$ 9,705	$ 9,431
Regulatory assets - current	74	164
Regulatory liabilities - long-term	1,202	977
Total Regulatory Assets	9,779	9,595
Regulatory liabilities - current	183	118
Total Regulatory Liabilities	1,385	1,095
Unrecognized pension and other postretirement costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	5,677	5,852
Future income tax [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	1,922	1,798
Environmental remediation costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	730	681
Deferred storm costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	432	128
Pension and other post retirement benefits deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	183	198
Revenue taxes [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	176	163
Net electric deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	102	121
Unamortized loss on reacquired debt [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	74	84
Surcharge for New York State assessment [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	73	90
Deferred derivative losses - long-term [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	40	60
O&R transition bond charges [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	39	44
Preferred Stock Redemption [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	29
Recoverable energy costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	23	14
Regulatory assets - current	5
Workers' compensation [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	19	23
Property tax reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	16	13
Regulatory liabilities - long-term	187	35
Other [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	170	162
Deferred derivative losses - current [Member]
Regulatory Assets [Line Items]
Regulatory assets - current	69	164
Allowance for cost removal less salvage [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	503	448
Net unbilled revenue deferrals [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	136	104
Regulatory liabilities - current	136
World Trade Center settlement proceeds [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	62	62
Long-term interest rate reconciliation [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	62	30
Carrying charges on transmission and distribution net plant [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	31	38
Gas line losses [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	14	21
Expenditure prudence proceeding [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	14	11
Energy efficiency programs [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	5	22
Other [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	188	206
Refundable energy costs - current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	82	51
Revenue decoupling mechanism [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	72	66
Electric Surcharge Offset [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	29
Deferred derivative gains - current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current		1
CECONY [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	8,972	8,750
Regulatory assets - current	60	140
Regulatory liabilities - long-term	1,077	861
Total Regulatory Assets	9,032	8,890
Regulatory liabilities - current	145	79
Total Regulatory Liabilities	1,222	940
CECONY [Member] \| Unrecognized pension and other postretirement costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	5,407	5,554
CECONY [Member] \| Future income tax [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	1,831	1,724
CECONY [Member] \| Environmental remediation costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	615	564
CECONY [Member] \| Deferred storm costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	309	80
CECONY [Member] \| Pension and other post retirement benefits deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	154	157
CECONY [Member] \| Revenue taxes [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	170	158
CECONY [Member] \| Net electric deferrals [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	102	121
CECONY [Member] \| Unamortized loss on reacquired debt [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	70	80
CECONY [Member] \| Surcharge for New York State assessment [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	68	82
CECONY [Member] \| Deferred derivative losses - long-term [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	20	44
CECONY [Member] \| Preferred Stock Redemption [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	29
CECONY [Member] \| Recoverable energy costs [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	23	14
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	187	35
CECONY [Member] \| Other [Member]
Regulatory Assets [Line Items]
Regulatory assets - long-term	155	149
CECONY [Member] \| Deferred derivative losses - current [Member]
Regulatory Assets [Line Items]
Regulatory assets - current	60	140
CECONY [Member] \| Allowance for cost removal less salvage [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	420	372
CECONY [Member] \| Net unbilled revenue deferrals [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	136	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	62	30
CECONY [Member] \| Carrying charges on transmission and distribution net plant [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	13	14
CECONY [Member] \| Gas line losses [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	14	21
CECONY [Member] \| Expenditure prudence proceeding [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	14	11
CECONY [Member] \| Energy efficiency programs [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	6	20
CECONY [Member] \| Other [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - long-term	163	192
CECONY [Member] \| Refundable energy costs - current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	48	12
CECONY [Member] \| Revenue decoupling mechanism [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	68	66
CECONY [Member] \| Electric Surcharge Offset [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current	29
CECONY [Member] \| Deferred derivative gains - current [Member]
Regulatory Assets [Line Items]
Regulatory liabilities - current		$ 1

Carrying amount as of the balance sheet date of capitalized costs of regulated entities that are expected to be recovered through revenue sources within one year or the normal operating cycle, if longer. Such costs are capitalized if they meet both of the following criteria: a. It is probable that future revenue in an amount at least equal to the capitalized cost will result from inclusion of that cost in allowable costs for rate-making purposes. b. Based on available evidence, the future revenue will be provided to permit recovery of the previously incurred cost rather than to provide for expected levels of similar future costs. If the revenue will be provided through an automatic rate-adjustment clause, this criterion requires that the regulator's intent clearly be to permit recovery of the previously incurred cost.

+ References+ Details

Capitalization - Additional Information (Detail) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012 Y	Dec. 31, 2011
Schedule of Capitalization [Line Items]
Common stock, shares, outstanding	21,976,200	21,976,200
Percentage limitation for income available for dividends	100.00%
Rolling average calculation of income available for dividends, years	2
Tax - exempt debt issued, value	$ 494
Long-term debt, fair value	12,935	12,744
Long-term debt	10,768	10,673
Debt instrument, covenant description	Con Edison's ratio of consolidated debt to consolidated capital to exceed 0.675 to 1
Covenant principal balance amount limit	100
Transition Bonds, issued in 2004 [Member]
Schedule of Capitalization [Line Items]
Long-term debt	25	29
Level 2 [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	12,299
Level 3 [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	636
CECONY [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	11,751	11,593
Long-term debt	9,845	9,745
CECONY [Member] \| Minimum [Member]
Schedule of Capitalization [Line Items]
Covenant principal balance amount limit	100
CECONY [Member] \| Maximum [Member]
Schedule of Capitalization [Line Items]
Covenant principal balance amount limit	150
CECONY [Member] \| Level 2 [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	11,115
CECONY [Member] \| Level 3 [Member]
Schedule of Capitalization [Line Items]
Long-term debt, fair value	$ 636

Number of shares of common stock outstanding. Common stock represent the ownership interest in a corporation.

+ References+ Details

Description of minimum financial levels (for example, tangible net worth and working capital) and achievement of certain financial ratios (for example, working capital ratio and debt service coverage ratio), and adherence to certain clauses which generally require or restrict certain actions (for example, entering into a debt arrangement with equal or greater seniority, and selling or discontinuing a certain business segment or material subsidiary) to be in compliance with the covenant clauses of the debt agreement. May also include a discussion of the adverse consequences that would result if the entity violates or fails to satisfy the covenants.

+ References+ Details

Carrying amount of long-term debt, net of unamortized discount or premium, including current and noncurrent amounts. Includes, but not limited to, notes payable, bonds payable, debentures, mortgage loans and commercial paper. Excludes capital lease obligations.

+ References+ Details

Capitalization - Schedule of Long-Term Debt Maturities (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012
Debt Instrument [Line Items]
2013	$ 706
2014	481
2015	495
2016	731
2017	7
CECONY [Member]
Debt Instrument [Line Items]
2013	700
2014	475
2015	350
2016	650
2017

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Carrying Amount	$ 10,768	$ 10,673
Fair Value	12,935	12,744
CECONY [Member]
Carrying Amount	9,845	9,745
Fair Value	$ 11,751	$ 11,593

+ References+ Details

Short-Term Borrowing - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Short-term Debt [Line Items]
Credit facility expiry date	Oct. 31, 2016
Maximum borrowing capacity	$ 2,250,000,000
Current amount available	1,000,000,000
Commercial paper, outstanding	539,000,000
Weighted average interest rate	0.30%
Line of credit facility, covenant terms	Ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2012 this ratio was 0.49 to 1 for Con Edison and CECONY); having liens on its assets in an aggregate amount exceeding 5 percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants.
Letters of credit outstanding under the credit agreement	131,000,000	173,000,000
CECONY [Member]
Short-term Debt [Line Items]
Commercial paper, outstanding	421,000,000
Weighted average interest rate	0.30%
Letters of credit outstanding under the credit agreement	121,000,000	150,000,000
Letter Of Credit [Member]
Short-term Debt [Line Items]
Current amount available	$ 1,200,000,000

Carrying value as of the balance sheet date of short-term borrowings using unsecured obligations issued by banks, corporations and other borrowers to investors. The maturities of these money market securities generally do not exceed 270 days.

+ References+ Details

Pension Benefits - Companies' Net Periodic Benefit Costs (Detail) (Pension benefits [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	$ 237	$ 190	$ 168
Interest cost on projected benefit obligation	547	560	556
Expected return on plan assets	(705)	(734)	(704)
Recognition of net actuarial loss	709	530	425
Recognition of prior service costs	8	8	8
NET PERIODIC BENEFIT COST	796	554	453
Amortization of regulatory asset	2	2	2
TOTAL PERIODIC BENEFIT COST	798	556	455
Cost capitalized	(277)	(185)	(157)
Reconciliation to rate level	(8)	(65)	(115)
Cost charged to operating expenses	513	306	183
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	220	177	157
Interest cost on projected benefit obligation	513	524	521
Expected return on plan assets	(670)	(698)	(670)
Recognition of net actuarial loss	670	501	401
Recognition of prior service costs	6	6	6
NET PERIODIC BENEFIT COST	739	510	415
Amortization of regulatory asset	2	2	2
TOTAL PERIODIC BENEFIT COST	741	512	417
Cost capitalized	(260)	(172)	(146)
Reconciliation to rate level	(12)	(68)	(113)
Cost charged to operating expenses	$ 469	$ 272	$ 158

Pension Benefits - Funded Status (Detail) (Pension benefits [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year	$ 11,825	$ 10,307	$ 9,408
Service cost - excluding administrative expenses	224	186	160
Interest cost on projected benefit obligation	547	560	556
Plan amendments			6
Net actuarial loss	1,323	1,251	636
Benefits paid	(513)	(479)	(459)
BENEFIT OBLIGATION AT END OF YEAR	13,406	11,825	10,307
Beginning Balance as of January 1, 2011	7,800	7,721	6,877
Actual return on plan assets	1,094	37	888
Employer contributions	785	542	443
Benefits paid	(513)	(479)	(459)
Administrative expenses	(31)	(21)	(28)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	9,135	7,800	7,721
FUNDED STATUS	(4,271)	(4,025)	(2,586)
Unrecognized net loss	5,594	5,351	3,915
Unrecognized prior service costs	23	30	38
Accumulated benefit obligation	11,911	10,595	9,319
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year	11,072	9,653	8,803
Service cost - excluding administrative expenses	209	174	149
Interest cost on projected benefit obligation	513	524	521
Plan amendments
Net actuarial loss	1,255	1,166	607
Benefits paid	(477)	(445)	(427)
BENEFIT OBLIGATION AT END OF YEAR	12,572	11,072	9,653
Beginning Balance as of January 1, 2011	7,406	7,340	6,544
Actual return on plan assets	1,040	33	846
Employer contributions	729	498	404
Benefits paid	(477)	(445)	(427)
Administrative expenses	(30)	(20)	(27)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	8,668	7,406	7,340
FUNDED STATUS	(3,904)	(3,666)	(2,313)
Unrecognized net loss	5,297	5,063	3,716
Unrecognized prior service costs	10	16	22
Accumulated benefit obligation	$ 11,116	$ 9,876	$ 8,694

Pension Benefits - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended				12 Months Ended				12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012 Other nonqualified supplemental defined benefit pension [Member]	Dec. 31, 2011 Other nonqualified supplemental defined benefit pension [Member]	Dec. 31, 2012 CECONY [Member]	Dec. 31, 2011 CECONY [Member]	Dec. 31, 2012 CECONY [Member] Other nonqualified supplemental defined benefit pension [Member]	Dec. 31, 2011 CECONY [Member] Other nonqualified supplemental defined benefit pension [Member]	Dec. 31, 2012 Pension benefits [Member]	Dec. 31, 2011 Pension benefits [Member]	Dec. 31, 2010 Pension benefits [Member]	Dec. 31, 2012 Pension benefits [Member] CECONY [Member]	Dec. 31, 2011 Pension benefits [Member] CECONY [Member]	Dec. 31, 2010 Pension benefits [Member] CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension liability	$ 246	$ 238
Increase to regulatory assets	233								225
Debit to OCI	1								1
Net loss estimated to be amortized					792				837
Prior service cost estimated to be amortized					4				5
Investments value	164	129			148	120
Accumulated benefit obligation			231	208			193	171	11,911	10,595	9,319	11,116	9,876	8,694
Assumptions used in calculating net periodic benefit cost									To determine the assumed discount rate, the Companies use a model that produces a yield curve based on yields on selected highly rated (Aa or higher by either Moody’s Investors Service (Moody’s) or Standard & Poor’s) corporate bonds. Bonds with insufficient liquidity, bonds with questionable pricing information and bonds that are not representative of the overall market are excluded from consideration. For example, the bonds used in the model cannot be callable, they must have a price between 50 and 200, the yield must lie between 1 percent and 20 percent, and the amount of the bond issue outstanding must be in excess of $50 million. The spot rates defined by the yield curve and the plan’s projected benefit payments are used to develop a weighted average discount rate.
Estimated future employer contributions									$ 893			$ 834

Pension Benefits - Actuarial Assumptions (Detail) (Pension benefits [Member])	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations	4.10%	4.70%	5.60%
Discount rate, net periodic benefit	4.70%	5.60%	6.05%
Expected return on plan assets	8.00%	8.50%	8.50%
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	4.35%	4.35%	4.35%
Rate of compensation increase	4.35%	4.35%	4.00%
O & R [Member]
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	4.25%	4.25%	4.25%
Rate of compensation increase	4.25%	4.25%	4.00%

An assumption as to the rate of return on plan assets reflecting the average rate of earnings expected on the funds invested or to be invested to provide for the benefits included in the benefit obligation.

+ References+ Details

Pension Benefits - Expected Benefit Payments (Detail) (Pension benefits [Member], USD $) In Millions, unless otherwise specified	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
2013	$ 554
2014	582
2015	608
2016	634
2017	659
2018-2022	3,635
CECONY [Member]
Defined Benefit Plan Disclosure [Line Items]
2013	517
2014	542
2015	567
2016	591
2017	614
2018-2022	$ 3,394

Pension Benefits - Plan Asset Allocations (Detail) (Pension benefits [Member])	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Equity Securities, Target Allocation, Minimum	55.00%
Equity Securities, Target Allocation, Maximum	65.00%
Debt Securities, Target Allocation, Minimum	27.00%
Debt Securities, Target Allocation, Maximum	33.00%
Real Estate, Target Allocation, Minimum	8.00%
Real Estate, Target Allocation, Maximum	12.00%
Plan Assets, Total	100.00%	100.00%	100.00%
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan Assets, Debt Securities	60.00%	61.00%	67.00%
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan Assets, Debt Securities	31.00%	32.00%	28.00%
Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan Assets, Debt Securities	9.00%	7.00%	5.00%

Pension Benefits - Fair Value of Plan Assets (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 20
Corporate Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets		94
Structured Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets		13
Other Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets		29
Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	833	572
Pension benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	9,878	8,516
Funds for retiree health benefits	(353)	(336)
Investments (excluding funds for retiree health benefits)	9,525	8,180
Pending activities	(390)	(380)
Total fair value of plan net assets	9,135	7,800	7,721	6,877
Pension benefits [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	5,172	4,423
Funds for retiree health benefits	(185)	(174)
Investments (excluding funds for retiree health benefits)	4,987	4,249
Pension benefits [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	3,853	3,385
Funds for retiree health benefits	(137)	(134)
Investments (excluding funds for retiree health benefits)	3,716	3,251
Pension benefits [Member] \| Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	853	708
Funds for retiree health benefits	(31)	(28)
Investments (excluding funds for retiree health benefits)	822	680
Pension benefits [Member] \| U.S. Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	2,637	2,467
Pension benefits [Member] \| U.S. Equity [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	2,637	2,467
Pension benefits [Member] \| International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	2,995	2,487
Pension benefits [Member] \| International Equity [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	2,242	1,850
Pension benefits [Member] \| International Equity [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	753	637
Pension benefits [Member] \| Private Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	20
Pension benefits [Member] \| Private Equity [Member] \| Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	20
Pension benefits [Member] \| U.S. Government Issues [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	1,626	1,570
Pension benefits [Member] \| U.S. Government Issues [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	1,626	1,570
Pension benefits [Member] \| Corporate Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	993	762
Total fair value of plan net assets		94	129
Pension benefits [Member] \| Corporate Bonds [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	993	668
Pension benefits [Member] \| Corporate Bonds [Member] \| Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments		94
Pension benefits [Member] \| Structured Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	30	13
Total fair value of plan net assets		13	87
Pension benefits [Member] \| Structured Assets [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	30
Pension benefits [Member] \| Structured Assets [Member] \| Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments		13
Pension benefits [Member] \| Other Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	123	96
Total fair value of plan net assets		29	66
Pension benefits [Member] \| Other Fixed Income [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	123	67
Pension benefits [Member] \| Other Fixed Income [Member] \| Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments		29
Pension benefits [Member] \| Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	833	572
Total fair value of plan net assets		572	398
Pension benefits [Member] \| Real Estate [Member] \| Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	833	572
Pension benefits [Member] \| Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	411	408
Pension benefits [Member] \| Cash and Cash Equivalents [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	83	13
Pension benefits [Member] \| Cash and Cash Equivalents [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	328	395
Pension benefits [Member] \| Futures [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	210	141
Pension benefits [Member] \| Futures [Member] \| Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments	210	93
Pension benefits [Member] \| Futures [Member] \| Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total investments		$ 48

Assets, usually stocks, bonds, and other investments, that have been segregated and restricted (usually in a trust) to provide benefits, at their fair value as of the measurement date. Plan assets include amounts contributed by the employer (and by employees for a contributory plan) and amounts earned from investing the contributions, less benefits paid. If a plan has liabilities other than for benefits, those non-benefit obligations may be considered as reductions of plan assets.

+ References+ Details

Pension Benefits - Reconciliation of Net Balances (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended												12 Months Ended
	Dec. 31, 2012 Real Estate [Member]	Dec. 31, 2012 Corporate Bonds [Member]	Dec. 31, 2012 Other Fixed Income [Member]	Dec. 31, 2012 Structured Assets [Member]	Dec. 31, 2012 Investments [Member]	Dec. 31, 2012 Funds for retiree health benefits [Member]	Dec. 31, 2012 Investments (excluding funds for retiree health benefits) [Member]	Dec. 31, 2012 Private Equity [Member]	Dec. 31, 2012 Pension benefits [Member]	Dec. 31, 2011 Pension benefits [Member]	Dec. 31, 2010 Pension benefits [Member]	Dec. 31, 2009 Pension benefits [Member]	Dec. 31, 2011 Pension benefits [Member] Real Estate [Member]	Dec. 31, 2011 Pension benefits [Member] Corporate Bonds [Member]	Dec. 31, 2011 Pension benefits [Member] Other Fixed Income [Member]	Dec. 31, 2011 Pension benefits [Member] Structured Assets [Member]	Dec. 31, 2011 Pension benefits [Member] Investments [Member]	Dec. 31, 2011 Pension benefits [Member] Funds for retiree health benefits [Member]	Dec. 31, 2011 Pension benefits [Member] Investments (excluding funds for retiree health benefits) [Member]
Defined Benefit Plan Disclosure [Line Items]
Beginning Balance as of January 1, 2011	$ 572	$ 94	$ 29	$ 13	$ 708	$ (28)	$ 680		$ 9,135	$ 7,800	$ 7,721	$ 6,877	$ 398	$ 129	$ 66	$ 87	$ 680	$ (30)	$ 650
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)	48				49	(2)	47	1					65	(9)	(1)	(1)	54	3	57
Assets Sold During the Period - Realized Gains	1			(6)	(5)		(5)							11	3	2	16	1	17
Purchases Sales and Settlements	212	(33)	(6)		192	(4)	188	19					109	(37)	(39)	(75)	(42)	(2)	(44)
Transfer in/(out) of Level 3		(61)	(23)	(7)	(91)	3	(88)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$ 833				$ 853	$ (31)	$ 822	$ 20	$ 9,135	$ 7,800	$ 7,721	$ 6,877	$ 572	$ 94	$ 29	$ 13	$ 708	$ (28)	$ 680

+ References+ Details

Other Postretirement Benefits - Net Periodic Postretirement Benefit Costs (Detail) (Other Postretirement Benefits [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule Of Other Postretirement Benefits [Line Items]
Service cost	$ 26	$ 26	$ 24
Interest cost on accumulated other postretirement benefit obligation	73	83	91
Expected return on plan assets	(85)	(88)	(86)
Recognition of net actuarial loss	98	88	92
Recognition of prior service cost	(21)	(10)	(12)
Recognition of transition obligation	2	4	3
NET PERIODIC BENEFIT COST	93	103	112
Cost capitalized	(32)	(35)	(39)
Reconciliation to rate level	20	14	4
Cost charged to operating expenses	81	82	77
CECONY [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Service cost	21	20	19
Interest cost on accumulated other postretirement benefit obligation	63	72	80
Expected return on plan assets	(75)	(78)	(78)
Recognition of net actuarial loss	87	80	85
Recognition of prior service cost	(18)	(11)	(14)
Recognition of transition obligation	2	4	3
NET PERIODIC BENEFIT COST	80	87	95
Cost capitalized	(28)	(29)	(33)
Reconciliation to rate level	16	13	1
Cost charged to operating expenses	$ 68	$ 71	$ 63

Other Postretirement Benefits - Schedule of Funded Status (Detail) (Other Postretirement Benefits [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$ 1,756	$ 1,642	$ 1,697
Service cost	26	25	24
Interest cost on accumulated postretirement benefit obligation	73	83	91
Amendments	(127)
Net actuarial loss/(gain)	(175)	109	(68)
Benefits paid and administrative expenses	(146)	(144)	(138)
Participant contributions	37	33	29
Medicare prescription subsidy	10	8	7
BENEFIT OBLIGATION AT END OF YEAR	1,454	1,756	1,642
CHANGE IN PLAN ASSETS
Beginning Balance as of January 1, 2011	947	942	866
Actual return on plan assets	124	20	89
Employer contributions	83	84	96
Participant contributions	37	33	29
Benefits paid	(144)	(132)	(138)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	1,047	947	942
FUNDED STATUS	(407)	(809)	(700)
Unrecognized net loss	251	563	483
Unrecognized prior service costs	(105)	(1)	(10)
Unrecognized net transition liability at January 1, 1993		4	7
CECONY [Member]
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	1,511	1,426	1,495
Service cost	21	20	19
Interest cost on accumulated postretirement benefit obligation	63	72	80
Amendments	(89)
Net actuarial loss/(gain)	(178)	86	(77)
Benefits paid and administrative expenses	(134)	(132)	(126)
Participant contributions	36	32	28
Medicare prescription subsidy	8	7	7
BENEFIT OBLIGATION AT END OF YEAR	1,238	1,511	1,426
CHANGE IN PLAN ASSETS
Beginning Balance as of January 1, 2011	840	839	777
Actual return on plan assets	109	19	78
Employer contributions	71	74	85
Participant contributions	36	32	28
Benefits paid	(134)	(124)	(129)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	922	840	839
FUNDED STATUS	(316)	(671)	(587)
Unrecognized net loss	197	496	440
Unrecognized prior service costs	(84)	(15)	(26)
Unrecognized net transition liability at January 1, 1993		$ 4	$ 7

Other PostretirementBenefits - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended		12 Months Ended	3 Months Ended	12 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012 CECONY [Member]	Mar. 31, 2012 Other Postretirement Benefits [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member] CECONY [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member] CECONY [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Reduction in postretirement life and health benefit plans				$ 102		$ 25
Decrease in postretirement health benefit obligation recorded as actuarial gain					306
Pension liability	246	238			402	355	355
Decrease to regulatory assets	233				408		372
Debit to OCI	1				6
Net loss estimated to be amortized			792		64		54
Prior service cost estimated to be amortized			4		(27)		(23)
Health care cost trend rate for net periodic benefit cost, current					6.00%
Health care cost trend rate for net periodic benefit cost					4.50%
Year for final trend rate for net periodic benefit cost					2018
Health care cost trend rate for benefit obligations, current					5.75%
Health care cost trend rate for benefit obligations					4.50%
Year for final trend rate for benefit obligations					2018
Expected contributions					$ 8	$ 8	$ 8

Other Postretirement Benefits - Schedule of Actuarial Assumptions (Detail) (Other Postretirement Benefits [Member])	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule Of Other Postretirement Benefits [Line Items]
Discount rate, net periodic benefit	4.55%	5.40%	5.95%
Expected return on plan assets	8.50%	8.50%	8.50%
CECONY [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Discount rate, benefit obligations	3.75%	4.55%	5.40%
O&R [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Discount rate, benefit obligations	4.05%	4.55%	5.40%

+ References+ Details

Other Postretirement Benefits - Schedule of Change of Assumed Health Care Cost Trend Rate (Detail) (Scenario, Forecast [Member], Other Postretirement Benefits [Member], USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2013
Schedule Of Other Postretirement Benefits [Line Items]
Effect on accumulated other postretirement benefit obligation, Increase	$ (12)
Effect on service cost and interest cost components for 2012, Increase
Effect on accumulated other postretirement benefit obligation, Decrease	12
Effect on service cost and interest cost components for 2012, Decrease
CECONY [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Effect on accumulated other postretirement benefit obligation, Increase	(31)
Effect on service cost and interest cost components for 2012, Increase	(2)
Effect on accumulated other postretirement benefit obligation, Decrease	27
Effect on service cost and interest cost components for 2012, Decrease	$ 1

Other Postretirement Benefits - Schedule of Expected Benefit Payments (Detail) (Other Postretirement Benefits [Member], USD $) In Millions, unless otherwise specified	Dec. 31, 2012
Schedule Of Other Postretirement Benefits [Line Items]
2013 - BENEFIT PAYMENTS	$ 101
2014 - BENEFIT PAYMENTS	101
2015 - BENEFIT PAYMENTS	101
2016 - BENEFIT PAYMENTS	98
2017 - BENEFIT PAYMENTS	97
2018-2022 - BENEFIT PAYMENTS	452
CECONY [Member]
Schedule Of Other Postretirement Benefits [Line Items]
2013 - BENEFIT PAYMENTS	91
2014 - BENEFIT PAYMENTS	90
2015 - BENEFIT PAYMENTS	89
2016 - BENEFIT PAYMENTS	87
2017 - BENEFIT PAYMENTS	86
2018-2022 - BENEFIT PAYMENTS	$ 389

Other Postretirement Benefits - Schedule of Plan Assets Allocations (Detail) (CECONY [Member], Other Postretirement Benefits [Member])										12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2012 Debt Securities [Member]	Dec. 31, 2011 Debt Securities [Member]	Dec. 31, 2010 Debt Securities [Member]	Dec. 31, 2012 Equity Securities [Member]	Dec. 31, 2011 Equity Securities [Member]	Dec. 31, 2010 Equity Securities [Member]	Dec. 31, 2013 Scenario, Forecast [Member]	Dec. 31, 2013 Scenario, Forecast [Member] Equity Security [Member]	Dec. 31, 2013 Scenario, Forecast [Member] Debt Securities [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Plan Assets	100.00%	100.00%	100.00%	38.00%	38.00%	33.00%	62.00%	62.00%	67.00%
Target Allocation, Minimum											57.00%	26.00%
Target Allocation, Maximum											73.00%	44.00%
Target Allocation Range, Total										100.00%

Other Postretirement Benefits - Fair Value of Plan Assets (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Other Fixed Income [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total fair value of plan net assets		$ 29
Other Postretirement Benefits [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	687	606
Funds for retiree health benefits	353	336
Investments (including funds for retiree health benefits)	1,040	942
Pending activities	7	5
Total fair value of plan net assets	1,047	947	942	866
Other Postretirement Benefits [Member] \| U.S. Equity [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	311	277
Other Postretirement Benefits [Member] \| International Equity [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	124	104
Other Postretirement Benefits [Member] \| Other Fixed Income [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	229	207
Other Postretirement Benefits [Member] \| Cash and Cash Equivalents [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	23	18
Level 1 [Member] \| Other Postretirement Benefits [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	127	115
Funds for retiree health benefits	185	174
Investments (including funds for retiree health benefits)	312	289
Pending activities
Level 1 [Member] \| Other Postretirement Benefits [Member] \| U.S. Equity [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	127	115
Level 1 [Member] \| Other Postretirement Benefits [Member] \| International Equity [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments
Level 1 [Member] \| Other Postretirement Benefits [Member] \| Other Fixed Income [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments
Level 1 [Member] \| Other Postretirement Benefits [Member] \| Cash and Cash Equivalents [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments
Level 2 [Member] \| Other Postretirement Benefits [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	560	491
Funds for retiree health benefits	137	134
Investments (including funds for retiree health benefits)	697	625
Pending activities
Level 2 [Member] \| Other Postretirement Benefits [Member] \| U.S. Equity [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	184	162
Level 2 [Member] \| Other Postretirement Benefits [Member] \| International Equity [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	124	104
Level 2 [Member] \| Other Postretirement Benefits [Member] \| Other Fixed Income [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	229	207
Level 2 [Member] \| Other Postretirement Benefits [Member] \| Cash and Cash Equivalents [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments	23	18
Level 3 [Member] \| Other Postretirement Benefits [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments
Funds for retiree health benefits	31	28
Investments (including funds for retiree health benefits)	31	28
Pending activities
Total fair value of plan net assets	31	28	219
Level 3 [Member] \| Other Postretirement Benefits [Member] \| U.S. Equity [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments
Level 3 [Member] \| Other Postretirement Benefits [Member] \| International Equity [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments
Level 3 [Member] \| Other Postretirement Benefits [Member] \| Other Fixed Income [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments
Total fair value of plan net assets			189
Level 3 [Member] \| Other Postretirement Benefits [Member] \| Cash and Cash Equivalents [Member]
Pension Plans, Postretirement and Other Employee Benefits [Line Items]
Total investments

+ References+ Details

Other Postretirement Benefits - Reconciliation of Fair Value Balances for Net Assets (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended						12 Months Ended
	Dec. 31, 2012 Other Fixed Income [Member]	Dec. 31, 2012 Funds for retiree health benefits [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member]	Dec. 31, 2011 Other Postretirement Benefits [Member]	Dec. 31, 2010 Other Postretirement Benefits [Member]	Dec. 31, 2009 Other Postretirement Benefits [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member] Level 3 [Member]	Dec. 31, 2011 Other Postretirement Benefits [Member] Level 3 [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member] Level 3 [Member] Other Fixed Income [Member]	Dec. 31, 2011 Other Postretirement Benefits [Member] Level 3 [Member] Other Fixed Income [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member] Level 3 [Member] Insurance Contracts [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member] Level 3 [Member] Funds for retiree health benefits [Member]	Dec. 31, 2011 Other Postretirement Benefits [Member] Level 3 [Member] Funds for retiree health benefits [Member]	Dec. 31, 2012 Other Postretirement Benefits [Member] Level 3 [Member] Investments (including funds for retiree health benefits) [Member]	Dec. 31, 2011 Other Postretirement Benefits [Member] Level 3 [Member] Investments (including funds for retiree health benefits) [Member]
Schedule Of Other Postretirement Benefits [Line Items]
Beginning Balance as of January 1, 2011	$ 29	$ (28)	$ 1,047	$ 947	$ 942	$ 866	$ 28	$ 219		$ 189			$ 189	$ 28	$ 30
Assets Still Held at Reporting Date - Unrealized Gains/(Losses)		(2)					2	(3)						2	(3)
Assets Sold During the Period - Realized(Losses)								(1)							(1)
Purchases Sales and Settlements	(6)	(4)					4	2						4	2
Transfers Out of Level 3							(3)	(189)		(189)			(189)	(3)
Ending Balance as of December 31, 2011		$ (31)	$ 1,047	$ 947	$ 942	$ 866	$ 31	$ 28						$ 31	$ 28

+ References+ Details

Environmental Matters - Accrued Liabilities and Regulatory Assets (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Accrued Liabilities:
Regulatory assets	$ 9,779	$ 9,595
Manufactured gas plant sites [Member]
Accrued Liabilities:
Accrued Liabilities	462	422
Other Superfund Sites [Member]
Accrued Liabilities:
Accrued Liabilities	83	67
Superfund Sites [Member]
Accrued Liabilities:
Accrued Liabilities	545	489
Regulatory assets	730	681
CECONY [Member]
Accrued Liabilities:
Regulatory assets	9,032	8,890
CECONY [Member] \| Manufactured gas plant sites [Member]
Accrued Liabilities:
Accrued Liabilities	351	307
CECONY [Member] \| Other Superfund Sites [Member]
Accrued Liabilities:
Accrued Liabilities	82	66
CECONY [Member] \| Superfund Sites [Member]
Accrued Liabilities:
Accrued Liabilities	433	373
Regulatory assets	$ 615	$ 564

Total costs accrued as of the balance sheet date for environmental loss contingencies.

+ References+ Details

Environmental Matters - Environmental Remediation Costs (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Remediation costs incurred	$ 31	$ 39
Insurance recoveries received*	4
CECONY [Member]
Remediation costs incurred	26	35
Insurance recoveries received*	$ 4

The charge against earnings in the period for known or estimated future costs arising from requirements to perform environmental remediation activities.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 230

-SubTopic 10

-Section 45

-Paragraph 28

-URI http://asc.fasb.org/extlink&oid=6943989&loc=d3e3602-108585

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Emerging Issues Task Force (EITF)

-Number 90-8

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 3: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 410

-SubTopic 30

-Section 50

-Paragraph 12

-URI http://asc.fasb.org/extlink&oid=6393242&loc=d3e13296-110859

Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher AICPA

-Name Statement of Position (SOP)

-Number 96-1

-Paragraph 170

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef

-Publisher AICPA

-Name Statement of Position (SOP)

-Number 96-1

-Paragraph 147, 148, 149, 150

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 6: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 5

-Paragraph 9, 10

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 143

-Paragraph 2

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Environmental Matters - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2010
CECONY [Member] \| Asbestos Proceedings [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
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

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Site Contingency [Line Items]
Regulatory assets	$ 9,779	$ 9,595
Asbestos suits [Member]
Site Contingency [Line Items]
Accrued liability	10	10
Regulatory assets	10	10
Workers' compensation [Member]
Site Contingency [Line Items]
Accrued liability	94	98
Regulatory assets	19	23
CECONY [Member]
Site Contingency [Line Items]
Regulatory assets	9,032	8,890
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

Total costs accrued as of the balance sheet date for environmental loss contingencies.

+ References+ Details

Other Material Contingencies - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012 LawSuits	Dec. 31, 2011
Operating Leased Assets [Line Items]
Number of suits pending against the company	93
Guarantee obligations maximum exposure	$ 859	$ 760
Maximum potential obligation	5
Leases [Member]
Operating Leased Assets [Line Items]
Guarantees issued	7
Energy [Member]
Operating Leased Assets [Line Items]
Guarantees issued	25
Construction [Member]
Operating Leased Assets [Line Items]
Guarantees issued	$ 8

Other Material Contingencies - Total Guarantees (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 859	$ 760
Energy transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	803
Intra-company guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	16
Other guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	40
0 - 3 years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	766
0 - 3 years [Member] \| Energy transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	716
0 - 3 years [Member] \| Intra-company guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	15
0 - 3 years [Member] \| Other guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	35
4 - 10 years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	30
4 - 10 years [Member] \| Energy transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	25
4 - 10 years [Member] \| Intra-company guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term
4 - 10 years [Member] \| Other guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	5
Greater than 10 years [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	63
Greater than 10 years [Member] \| Energy transactions [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	62
Greater than 10 years [Member] \| Intra-company guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1
Greater than 10 years [Member] \| Other guarantees [Member]
Guarantor Obligations [Line Items]
Total guarantees, by type and term

Electricity Purchase Agreements - Summary of Significant Terms of Electricity Purchase Agreement (Detail) (CECONY [Member])	12 Months Ended
	Dec. 31, 2012 MW
Long-term Contract for Purchase of Electric Power [Line Items]
Contracted Output (MW)	500
Indian Point [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	1,299
Contracted Output (MW)	350
Contract Start Date	August 2001
Contract Term (Years)	16 years
Independence [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	1,254
Contracted Output (MW)	697
Contract Start Date	November 1994
Contract Term (Years)	20 years
Linden Cogeneration [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	1,035
Contracted Output (MW)	628
Contract Start Date	May 1992
Contract Term (Years)	25 years
Astoria Energy [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	640
Contracted Output (MW)	500
Contract Start Date	May 2006
Contract Term (Years)	10 years
Selkirk [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	446
Contracted Output (MW)	265
Contract Start Date	September 1994
Contract Term (Years)	20 years
Brooklyn Navy Yard [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	322
Contracted Output (MW)	263
Contract Start Date	November 1996
Contract Term (Years)	40 years
Indeck Corinth [Member]
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	147
Contracted Output (MW)	132
Contract Start Date	July 1995
Contract Term (Years)	20 years

Leases - Schedule of Capital Leases (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Leases
Utility Plant	$ 3	$ 9
Common [Member]
Leases
Utility Plant	3	8
Transmission [Member]
Leases
Utility Plant		1
CECONY [Member]
Leases
Utility Plant	2	7
CECONY [Member] \| Common [Member]
Leases
Utility Plant	2	6
CECONY [Member] \| Transmission [Member]
Leases
Utility Plant		$ 1

Property, plant, or equipment held under lease agreements classified as an asset.

+ References+ Details

Leases - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended											12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012 Minimum [Member]	Dec. 31, 2012 Maximum [Member]	Dec. 31, 2012 Tax deficiency paid in December 2005 [Member]	Dec. 31, 2012 Interest in April 2006 [Member]	Dec. 31, 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]	Dec. 31, 2012 CECONY [Member]	Dec. 31, 2011 CECONY [Member]
Operating Leased Assets [Line Items]
Accumulated amortization	$ 1.0	$ 66.0										$ 0.4	$ 65.0
Lease in lease out total investment	259
Lease in lease out total financed by equity	93
Lease in lease out total financed by long-term debt	166
The company's investment in leverage leases	(76)	(55)
Gross investment in leverage leases	228	234
Deferred tax liabilities	304	289
Tax deficiency paid to IRS					0.3
Interest paid related to tax deficiency						0.2
Disallowed deduction							416	35	40	41	42
Estimated charge after-tax			150	170
Defray interest charges	447
Cash proceeds from negotiate termination of the transactions	$ 210

Leases - Future Minimum Lease Commitments (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012
Leases
2013
2014	1
2015	1
2016
2017
All years thereafter	1
Total	3
Less: amount representing interest	1
Present value of net minimum lease payment	2
CECONY [Member]
Leases
2013
2014	1
2015	1
2016
2017
All years thereafter	1
Total	3
Less: amount representing interest	1
Present value of net minimum lease payment	$ 2

Leases - Future Minimum Rental Payments for Operating Leases (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012
Leases
2013	$ 52
2014	47
2015	15
2016	14
2017	14
All years thereafter	91
Total	233
CECONY [Member]
Leases
2013	49
2014	43
2015	12
2016	11
2017	11
All years thereafter	71
Total	$ 197

Goodwill - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Goodwill [Line Items]
Goodwill	$ 429	$ 429
O&R [Member]
Goodwill [Line Items]
Goodwill	406	406
Energy services acquired [Member]
Goodwill [Line Items]
Goodwill	23	23
CECONY [Member]
Goodwill [Line Items]
Goodwill	245
O & R [Member]
Goodwill [Line Items]
Goodwill		$ 161

Carrying amount as of the balance sheet date, which is the cumulative amount paid and (if applicable) the fair value of any noncontrolling interest in the acquiree, adjusted for any amortization recognized prior to the adoption of any changes in generally accepted accounting principles (as applicable) and for any impairment charges, in excess of the fair value of net assets acquired in one or more business combination transactions.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 141R

-Paragraph 68

-Subparagraph l

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 350

-SubTopic 20

-Section 50

-Paragraph 1

-URI http://asc.fasb.org/extlink&oid=14024403&loc=d3e13816-109267

Reference 3: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

-Topic 350

-SubTopic 20

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-Paragraph 1

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Reference 4: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 142

-Paragraph 45

-Subparagraph e

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 5: http://www.xbrl.org/2003/role/presentationRef

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-Name Statement of Financial Accounting Standard (FAS)

-Number 142

-Paragraph 43

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Reference 6: http://www.xbrl.org/2003/role/presentationRef

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-Name Statement of Financial Accounting Standard (FAS)

-Number 141R

-Paragraph 72

-Subparagraph d

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 142

-Paragraph 45

-Subparagraph e

-Clause 1

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 141R

-Paragraph 34

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Income Tax - Schedule of Components of Income Tax (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Income Tax [Line Items]
State - Current	$ 29	$ 56	$ 23
State - Deferred	97	63	106
Federal - Current	(13)	53	(144)
Federal - Deferred	493	434	569
Amortization of investment tax credits	(6)	(6)	(6)
Total charge to income tax expense	600	600	548
CECONY [Member]
Income Tax [Line Items]
State - Current	53	53	13
State - Deferred	53	55	100
Federal - Current	110	43	(139)
Federal - Deferred	318	413	527
Amortization of investment tax credits	(5)	(6)	(6)
Total charge to income tax expense	$ 529	$ 558	$ 495

The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted federal tax law to the domestic taxable Income or Loss from continuing operations.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 740

-SubTopic 10

-Section S99

-Paragraph 1

-Subparagraph (SAB TOPIC 6.I.7)

-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Glossary Current Tax Expense (or Benefit)

-URI http://asc.fasb.org/extlink&oid=6509736

Reference 3: http://www.xbrl.org/2003/role/presentationRef

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-Topic 740

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-Name Accounting Standards Codification

-Topic 235

-SubTopic 10

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-Paragraph 1

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-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

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Reference 6: http://www.xbrl.org/2003/role/presentationRef

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-Name Regulation S-X (SX)

-Number 210

-Section 08

-Paragraph h

-Article 4

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-Number 109

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Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Staff Accounting Bulletin (SAB)

-Number Topic 6

-Section I

-Paragraph Question 1-7

+ Details

The component of income tax expense for the period representing amounts paid or payable (or refundable) as determined by applying the provisions of enacted state and local tax law to relevant amounts of taxable Income or Loss from continuing operations.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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-Topic 740

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-Paragraph 1

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-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

Reference 2: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Glossary Current Tax Expense (or Benefit)

-URI http://asc.fasb.org/extlink&oid=6509736

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-Name Accounting Standards Codification

-Topic 740

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-Paragraph 9

-Subparagraph (a)

-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

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-Name Accounting Standards Codification

-Topic 235

-SubTopic 10

-Section S99

-Paragraph 1

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-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

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Reference 6: http://www.xbrl.org/2003/role/presentationRef

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-Name Regulation S-X (SX)

-Number 210

-Section 08

-Paragraph h

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-Number Topic 6

-Section I

-Subsection 7

Reference 8: http://www.xbrl.org/2003/role/presentationRef

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-Name Statement of Financial Accounting Standard (FAS)

-Number 109

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

The component of total income tax expense for the period comprised of the increase (decrease) during the period in the entity's domestic deferred tax assets and liabilities attributable to continuing operations as determined by applying the provisions of the federally enacted tax law.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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-Topic 740

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-Paragraph 1

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-URI http://asc.fasb.org/extlink&oid=6889476&loc=d3e330036-122817

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-Topic 235

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-Paragraph 1

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-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

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-Name Regulation S-X (SX)

-Number 210

-Section 08

-Paragraph h

-Article 4

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-Number Topic 6

-Section I

-Subsection 7

Reference 5: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

-Glossary Deferred Tax Expense (or Benefit)

-URI http://asc.fasb.org/extlink&oid=6510177

Reference 6: http://www.xbrl.org/2003/role/presentationRef

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-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

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-Name Statement of Financial Accounting Standard (FAS)

-Number 109

-Paragraph 8, 16, 17, 289

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Reference 8: http://www.xbrl.org/2003/role/presentationRef

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

The component of total income tax expense for the period comprised of the increase (decrease) in the entity's state and local deferred tax assets and liabilities attributable to continuing operations as determined by applying the provisions of the applicable enacted tax laws.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

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-Topic 235

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-Paragraph 1

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-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

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-Name Regulation S-X (SX)

-Number 210

-Section 08

-Paragraph h

-Article 4

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-Name Staff Accounting Bulletin (SAB)

-Number Topic 6

-Section I

-Subsection 7

Reference 5: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

-Glossary Deferred Tax Expense (or Benefit)

-URI http://asc.fasb.org/extlink&oid=6510177

Reference 6: http://www.xbrl.org/2003/role/presentationRef

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-Topic 740

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-Subparagraph (b)

-URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32639-109319

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-Name Statement of Financial Accounting Standard (FAS)

-Number 109

-Paragraph 8, 16, 17, 289

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Reference 8: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Statement of Financial Accounting Standard (FAS)

-Number 109

-Paragraph 45

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-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

The sum of the current income tax expense or benefit and the deferred income tax expense or benefit pertaining to pretax Income or Loss from continuing operations; income tax expense or benefit may include interest and penalties on tax uncertainties based on the entity's accounting policy.

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name Accounting Standards Codification

-Topic 235

-SubTopic 10

-Section S99

-Paragraph 1

-Subparagraph (SX 210.4-08.(h))

-URI http://asc.fasb.org/extlink&oid=6881521&loc=d3e23780-122690

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-Publisher SEC

-Name Regulation S-X (SX)

-Number 210

-Section 08

-Paragraph h

-Article 4

Reference 3: http://www.xbrl.org/2003/role/presentationRef

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-Name Accounting Standards Codification

-Topic 740

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-Paragraph 10

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-Subparagraph (a),(b)

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-Paragraph 25

-URI http://asc.fasb.org/extlink&oid=21917399&loc=d3e32247-109318

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-Name Statement of Financial Accounting Standard (FAS)

-Number 109

-Paragraph 45, 46

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Reference 7: http://www.xbrl.org/2003/role/presentationRef

-Publisher FASB

-Name FASB Interpretation (FIN)

-Number 48

-Paragraph 15, 16, 19

-LegacyDoc This reference is SUPERSEDED by the Accounting Standards Codification effective for interim and annual periods ending after September 15, 2009. This reference is included to help users transition from the previous accounting hierarchy and will be removed from future versions of this taxonomy.

+ Details

Income Tax - Schedule of Differences on Deferred Tax Assets and Liabilities (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Schedule Of Deferred Income Tax Assets And Liabilities [Line Items]
Depreciation	$ 4,210	$ 3,652
Regulatory asset - future income tax	2,061.0	1,971.0
Unrecognized pension and other postretirement costs	2,472	2,554
State income tax	1,060	920
Capitalized overheads	565	536
Pension	736	682
Investment tax credits	49	55
Other	931	743
Total deferred tax liabilities	12,084	11,113
Unrecognized pension and other postretirement costs	2,472	2,554
State income tax	382	336
Regulatory liability - future income tax	126	173
Other	1,028	753
Total deferred tax assets	4,008	3,816
Net deferred tax liabilities and investment tax credits	8,076	7,297
Deferred income taxes and investment tax credits - Noncurrent	8,372	7,563
Deferred tax assets - Current	(296)	(266)
Net deferred tax liabilities and investment tax credits	8,076	7,297
CECONY [Member]
Schedule Of Deferred Income Tax Assets And Liabilities [Line Items]
Depreciation	3,909	3,464
Regulatory asset - future income tax	1,962.0	1,891.0
Unrecognized pension and other postretirement costs	2,202	2,255
State income tax	897	811
Capitalized overheads	496	470
Pension	730	709
Investment tax credits	47	52
Other	528	467
Total deferred tax liabilities	10,771	10,119
Unrecognized pension and other postretirement costs	2,202	2,255
State income tax	357	309
Regulatory liability - future income tax	117	167
Other	836	624
Total deferred tax assets	3,512	3,355
Net deferred tax liabilities and investment tax credits	7,259	6,764
Deferred income taxes and investment tax credits - Noncurrent	7,452	6,921
Deferred tax assets - Current	(193)	(157)
Net deferred tax liabilities and investment tax credits	$ 7,259	$ 6,764

Income Tax - Schedule of Income Tax Reconciliation (Detail)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Income Tax Rate Reconciliation [Line Items]
Federal	35.00%	35.00%	35.00%
State income tax	4.00%	5.00%	5.00%
Cost of removal	(4.00%)	(4.00%)	(4.00%)
Other	(1.00%)		(1.00%)
Effective Tax Rate	34.00%	36.00%	35.00%
CECONY [Member]
Income Tax Rate Reconciliation [Line Items]
Federal	35.00%	35.00%	35.00%
State income tax	4.00%	5.00%	5.00%
Cost of removal	(4.00%)	(4.00%)	(4.00%)
Other	(1.00%)		(1.00%)
Effective Tax Rate	34.00%	36.00%	35.00%

A ratio calculated by dividing the reported amount of income tax expense attributable to continuing operations for the period by GAAP-basis pretax income from continuing operations.

+ References+ Details

The domestic federal statutory tax rate applicable under enacted tax laws to the Company's pretax income from continuing operations for the period. The "statutory" tax rate is the regular tax rate if there are alternative tax systems.

+ References+ Details

Income Tax - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward	$ 11	$ 632
Accrued liability for uncertain tax position	72
Uncertain tax positions	86
Increase in current liabilities	44
Reduction to current deferred tax assets	42
Unrecognized tax benefits	86	130	93	86
CECONY [Member]
Operating Loss Carryforwards [Line Items]
Accrued liability for uncertain tax position	66
Uncertain tax positions	74
Increase in current liabilities	36
Reduction to current deferred tax assets	38
Unrecognized tax benefits	74	114	79	92
New York State [Member]
Operating Loss Carryforwards [Line Items]
Net operating loss carryforward	284
Unrecognized tax benefits	7
New York State [Member] \| CECONY [Member]
Operating Loss Carryforwards [Line Items]
Unrecognized tax benefits	$ 1

Income Tax - Summary of Unrecognized Tax Benefits (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Income Tax Reconciliation [Line Items]
Balance at January 1	$ 130	$ 93	$ 86
Additions based on tax positions related to the current year	12	76	5
Additions based on tax positions of prior years		4	67
Reductions for tax positions of prior years	(57)	(43)	(4)
Settlements	1		(61)
Balance at December 31	86	130	93
CECONY [Member]
Income Tax Reconciliation [Line Items]
Balance at January 1	114	79	92
Additions based on tax positions related to the current year	11	74	4
Additions based on tax positions of prior years		3	49
Reductions for tax positions of prior years	(52)	(42)	(4)
Settlements	1		(62)
Balance at December 31	$ 74	$ 114	$ 79

Stock-Based Compensation - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012 Y	Dec. 31, 2011	Dec. 31, 2010
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option awards	10,000,000
Stock option awards, LTIP	10,000,000
Restricted stock	4,000,000
Stock option vesting period	3 years
Intrinsic value for outstanding options	$ 8,000,000	$ 18,000,000
Intrinsic value for exercised options	5,000,000	21,000,000
Cash received for payment of the exercise price	14,000,000	88,000,000
Remaining contractual life, years	2 years
INCOME TAX EXPENSE	600,000,000	600,000,000	548,000,000
Total expense recognized in future periods	2,000,000
Weighted average period	1
Number of units issued annually to each individual	1,785
Number of units issued	30,242
Number of units issued annually to each individual price	$ 58.89
Maximum employer contribution match	1
Amount employee contribution for employer match	9
Maximum employee investment per year	25,000
Maximum percentage allowed to invest	20.00%
Shares purchased on the open market	665,718	721,520	738,951
Weighted average share price per share, on shares purchased on open market	$ 59.72	$ 52.50	$ 45.52
EIP portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%
Factor used for adjustment of Performance awards, low end	0.00%
Factor used for adjustment of Performance awards, high end	200.00%
TSR portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%
Factor used for adjustment of Performance awards, low end	0.00%
Factor used for adjustment of Performance awards, high end	150.00%
Performance-based restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average period	1
Unvested compensation expense	23,000,000
Stock options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
INCOME TAX EXPENSE		2,000,000	6,000,000
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option vesting period	10 years
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Intrinsic value for outstanding options	6,000,000	14,000,000
INCOME TAX EXPENSE	529,000,000	558,000,000	495,000,000
Total expense recognized in future periods	1,000,000
Weighted average period	1
CECONY [Member] \| Performance-based restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average period	1
Unvested compensation expense	$ 19,000,000

Stock-Based Compensation - Stock-Based Compensation Expense (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 16	$ 52	$ 29
Income Tax Benefit	6	21	12
Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	1	3	1
Performance-based restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	14	48	27
Non-officer director deferred stock compensation [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	1	1	1
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	15	48	27
Income Tax Benefit	6	20	11
CECONY [Member] \| Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	1	3	1
CECONY [Member] \| Performance-based restricted stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	13	44	25
CECONY [Member] \| Non-officer director deferred stock compensation [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 1	$ 1	$ 1

Stock-Based Compensation - Summary of Status of Stock Options Awarded (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Exercise Price Outstanding, Beginning Balance	$ 43.046
Weighted Average Exercise Price, Exercised	$ 43.128
Weighted Average Exercise Price, Forfeited	$ 41.665
Weighted Average Exercise Price Outstanding, Ending Balance	$ 43.008
Outstanding Shares, Beginning Balance	927,025
Exercised, Shares	(318,550)
Forfeited, Shares	(2,000)
Outstanding Shares, Ending Balance	606,475
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted Average Exercise Price Outstanding, Beginning Balance	$ 43.066
Weighted Average Exercise Price, Exercised	$ 43.238
Weighted Average Exercise Price, Forfeited	$ 43.005
Weighted Average Exercise Price Outstanding, Ending Balance	$ 42.973
Outstanding Shares, Beginning Balance	740,875
Exercised, Shares	(258,700)
Forfeited, Shares	(1,000)
Outstanding Shares, Ending Balance	481,175

The number of shares reserved for issuance under stock option agreements awarded under the plan that validly exist and are outstanding as of the balance sheet date, including vested options.

+ References+ Details

Number of share options (or share units) exercised during the current period.

+ References+ Details

Stock-Based Compensation - Summary of Stock Options Outstanding (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Remaining Contractual Life	2 years
Options Outstanding / Exercisable	606,475	927,025
Weighted Average Exercise Price	$ 43.008	$ 43.046
2006 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Remaining Contractual Life	3 years
Options Outstanding / Exercisable	228,250
Weighted Average Exercise Price	$ 43.870
2005 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Remaining Contractual Life	2 years
Options Outstanding / Exercisable	170,125
Weighted Average Exercise Price	$ 42.243
2004 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Remaining Contractual Life	1 year
Options Outstanding / Exercisable	157,000
Weighted Average Exercise Price	$ 44.060
2003 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Outstanding / Exercisable	51,100
Weighted Average Exercise Price	$ 38.470
2003 [Member] \| Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Remaining Contractual Life	1 year
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Outstanding / Exercisable	481,175	740,875
Weighted Average Exercise Price	$ 42.973	$ 43.066
CECONY [Member] \| 2006 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Outstanding / Exercisable	188,150
Weighted Average Exercise Price	$ 43.841
CECONY [Member] \| 2005 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Outstanding / Exercisable	139,025
Weighted Average Exercise Price	$ 42.258
CECONY [Member] \| 2004 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Outstanding / Exercisable	112,400
Weighted Average Exercise Price	$ 44.072
CECONY [Member] \| 2003 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Outstanding / Exercisable	41,600
Weighted Average Exercise Price	$ 38.470

The number of shares reserved for issuance under stock option agreements awarded under the plan that validly exist and are outstanding as of the balance sheet date, including vested options.

+ References+ Details

Stock-Based Compensation - Summary of Changes in Status of Restricted Stock (Detail) (Restricted Stock Units [Member], USD $)	12 Months Ended
	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares, Beginning Balance	65,420
Granted, shares	22,860
Vested, shares	(21,130)
Forfeited, shares	(2,010)
Non-vested shares, Ending Balance	65,140
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	$ 45.049
Weighted Average Grant Date Granted	$ 58.420
Weighted Average Grant Date Vested	$ 39.610
Weighted Average Grant Date Forfeited	$ 50.452
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	$ 51.339
CECONY [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares, Beginning Balance	61,920
Granted, shares	21,660
Vested, shares	(19,980)
Forfeited, shares	(1,910)
Non-vested shares, Ending Balance	61,690
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	$ 45.049
Weighted Average Grant Date Granted	$ 58.420
Weighted Average Grant Date Vested	$ 39.610
Weighted Average Grant Date Forfeited	$ 50.600
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	$ 51.334

The weighted average fair value at grant date for nonvested equity-based awards issued during the period on other than stock (or unit) option plans (for example, phantom stock or unit plan, stock or unit appreciation rights plan, performance target plan).

+ References+ Details

The number of non-vested equity-based payment instruments, excluding stock (or unit) options, that validly exist and are outstanding as of the balance sheet date.

+ References+ Details

The weighted average fair value of nonvested awards on equity-based plans excluding option plans (for example, phantom stock or unit plan, stock or unit appreciation rights plan, revenue or profit achievement stock award plan) for which the employer is contingently obligated to issue equity instruments or transfer assets to an employee who has not yet satisfied service or performance criteria necessary to gain title to proceeds from the sale of the award or underlying shares or units.

+ References+ Details

The weighted average fair value as of grant date pertaining to an equity-based award plan other than a stock (or unit) option plan for which the grantee gained the right during the reporting period, by satisfying service and performance requirements, to receive or retain shares or units, other instruments, or cash in accordance with the terms of the arrangement.

+ References+ Details

Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Detail)	12 Months Ended
	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate, Maximum	0.15%
Risk-free interest rate, Minimum	3.69%
Expected term	3 years
Expected volatility	15.27%

The estimated measure of the percentage by which a share price is expected to fluctuate during a period. Volatility also may be defined as a probability-weighted measure of the dispersion of returns about the mean. The volatility of a share price is the standard deviation of the continuously compounded rates of return on the share over a specified period. That is the same as the standard deviation of the differences in the natural logarithms of the stock prices plus dividends, if any, over the period.

+ References+ Details

Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012
EIP portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares, Beginning Balance	474,517
Granted	191,280
Vested	(36,075)
Forfeited	(10,812)
Non-vested shares, Ending Balance	618,910
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	$ 46.660
Weighted Average Date Granted	$ 58.852
Weighted Average Date Vested	$ 39.663
Weighted Average Grant Date Forfeited	$ 52.247
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	$ 50.738
TSR portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares, Beginning Balance	474,517
Granted	191,280
Vested	(36,075)
Forfeited	(10,812)
Non-vested shares, Ending Balance	618,910
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	$ 42.511
Weighted Average Date Granted	$ 49.507
Weighted Average Date Vested	$ 41.868
Weighted Average Date Forfeited	$ 45.452
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	$ 44.659
CECONY [Member] \| EIP portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares, Beginning Balance	387,379
Granted	157,348
Vested	(33,653)
Forfeited	(8,373)
Non-vested shares, Ending Balance	502,701
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	$ 46.599
Weighted Average Date Granted	$ 58.838
Weighted Average Date Vested	$ 39.666
Weighted Average Grant Date Forfeited	$ 53.183
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	$ 50.783
CECONY [Member] \| TSR portion [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares, Beginning Balance	387,379
Granted	157,348
Vested	(33,653)
Forfeited	(8,373)
Non-vested shares, Ending Balance	502,701
Weighted Average Grant Date Fair Value Non-vested, Beginning Balance	$ 42.542
Weighted Average Date Granted	$ 49.416
Weighted Average Date Vested	$ 41.869
Weighted Average Date Forfeited	$ 46.023
Weighted Average Grant Date Fair Value Non-vested, Ending Balance	$ 44.681

Financial Information by Business Segment - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	1 Months Ended
	Oct. 31, 2012 MW Company	Jul. 31, 2012 MW	Jul. 31, 2012 Contingent consideration [Member]	Oct. 31, 2012 Deposits relating to power purchase agreements [Member]	Jul. 31, 2012 Deposits relating to power purchase agreements [Member]	Oct. 31, 2012 Construction [Member]	Jul. 31, 2012 Construction [Member]	Oct. 31, 2012 Construction work in progress [Member]	Dec. 31, 2012 Con Edison Development [Member]
Segment Reporting Information [Line Items]
All assets of the business segments									$ 228
Solar energy projects	40	70
Purchase price of solar energy development company	$ 51	$ 288	$ 2	$ 12	$ 4	$ 200	$ 340	$ 39
Number of companies purchased	2

Financial Information by Business Segment - Financial Data for the Business Segments (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Segment Reporting Information [Line Items]
Depreciation and amortization	$ 955	$ 884	$ 840
Operating income	2,339	2,239	2,120
INCOME TAX EXPENSE	600	600	548
CECONY - Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	8,176	8,228	8,376
Inter-segment revenues	15	12	12
Depreciation and amortization	710	656	623
Operating income	1,693	1,695	1,549
Interest charges	423	414	424
INCOME TAX EXPENSE	393	481	371
Total assets	28,339	27,123	25,045
Construction expenditures	1,375	1,354	1,421
CECONY - Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,415	1,521	1,541
Inter-segment revenues	5	5	5
Depreciation and amortization	120	110	102
Operating income	346	295	310
Interest charges	82	78	82
INCOME TAX EXPENSE	99	43	91
Total assets	5,925	5,518	5,095
Construction expenditures	426	335	334
CECONY - Steam [Member]
Segment Reporting Information [Line Items]
Operating revenues	596	683	656
Inter-segment revenues	77	79	74
Depreciation and amortization	64	63	62
Operating income	54	93	63
Interest charges	40	42	43
INCOME TAX EXPENSE	22	43	29
Total assets	2,621	2,577	2,465
Construction expenditures	108	89	111
O&R - Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	592	641	692
Inter-segment revenues
Depreciation and amortization	38	35	32
Operating income	83	81	74
Interest charges	19	20	22
INCOME TAX EXPENSE	17	21	18
Total assets	1,960	1,755	1,630
Construction expenditures	98	79	99
O&R - Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	203	214	218
Inter-segment revenues
Depreciation and amortization	15	13	12
Operating income	40	33	34
Interest charges	10	12	12
INCOME TAX EXPENSE	11	9	8
Total assets	706	722	686
Construction expenditures	39	32	36
O&R - Other [Member]
Segment Reporting Information [Line Items]
Operating revenues
Inter-segment revenues
Depreciation and amortization
Operating income
Interest charges	2	2	1
Total assets	5	8	32
Competitive energy businesses [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,213	1,617	1,883
Inter-segment revenues	8	13	9
Depreciation and amortization	8	7	9
Operating income	125	46	97
Interest charges	1	(1)	(3)
INCOME TAX EXPENSE	52	20	37
Total assets	1,061	856	828
Construction expenditures	492	114	28
Other Revenues And Eliminations In Segment Information [Member]
Segment Reporting Information [Line Items]
Operating revenues	(7)	(18)	(41)
Inter-segment revenues	(8)	(13)	(9)
Depreciation and amortization
Operating income	(2)	(4)	(7)
Interest charges	27	27	28
Total assets	592	655	567
CECONY [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,187	10,432	10,573
Inter-segment revenues
Depreciation and amortization	894	829	787
Operating income	2,093	2,083	1,922
Interest charges	545	534	549
INCOME TAX EXPENSE	529	558	495
Total assets	36,885	35,218	32,605
Construction expenditures	1,909	1,778	1,866
O&R [Member]
Segment Reporting Information [Line Items]
Operating revenues	795	855	910
Inter-segment revenues
Depreciation and amortization	53	48	44
Operating income	123	114	108
Interest charges	31	34	35
INCOME TAX EXPENSE	28	30	26
Total assets	2,671	2,485	2,348
Construction expenditures	137	111	135
Consolidation adjustments [Member]
Segment Reporting Information [Line Items]
Operating revenues
Inter-segment revenues	(97)	(96)	(91)
Depreciation and amortization
Operating income
Con Edison [Member]
Segment Reporting Information [Line Items]
Operating revenues	12,188	12,886	13,325
Inter-segment revenues
Depreciation and amortization	955	884	840
Operating income	2,339	2,239	2,120
Interest charges	604	594	609
INCOME TAX EXPENSE	594	617	554
Total assets	41,209	39,214	36,348
Construction expenditures	$ 2,538	$ 2,003	$ 2,029

The sum of the current income tax expense or benefit and the deferred income tax expense or benefit pertaining to continuing operations.

+ References+ Details

The cost of borrowed funds accounted for as interest that was charged against earnings during the period.

+ References+ Details

Derivative Instruments and Hedging Activities - Energy Price Hedging Fair Values (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Derivatives And Hedging Activities [Line Items]
Fair value of net derivative assets/(liabilities) - gross	$ (90)	$ (249)
Impact of netting of cash collateral	84	110
Fair value of net derivative assets/(liabilities) - net	(6)	(139)
CECONY [Member]
Derivatives And Hedging Activities [Line Items]
Fair value of net derivative assets/(liabilities) - gross	(56)	(144)
Impact of netting of cash collateral	47	46
Fair value of net derivative assets/(liabilities) - net	$ (9)	$ (98)

Derivative Instruments and Hedging Activities - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 113
Makeup of net credit exposure, with investment-grade counterparties	41
Makeup of net credit exposure with commodity exchange brokers	41
Makeup of net credit exposure independent system operators	28
Makeup of net credit exposure non-investment grade/non-rated counterparties	3
Number of contracts considered derivatives	1147
Collateral posted
Additional Collateral Required Due To Loss Of Unsecured Credit [Member]
Investment Holdings [Line Items]
Collateral posted	24
Additional collateral aggregate fair value down below investment grade [Member]
Investment Holdings [Line Items]
Collateral posted	24
Purchased power expense [Member]
Investment Holdings [Line Items]
Unrealized gain (loss) on derivatives	82	(34)
Non-utility revenue [Member]
Investment Holdings [Line Items]
Unrealized gain (loss) on derivatives	(14)	11
CECONY [Member]
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	19
Makeup of net credit exposure, with investment-grade counterparties	1
Makeup of net credit exposure with commodity exchange brokers	18
Number of contracts considered derivatives	581
Collateral posted
CECONY [Member] \| Additional Collateral Required Due To Loss Of Unsecured Credit [Member]
Investment Holdings [Line Items]
Collateral posted	10
CECONY [Member] \| Additional collateral aggregate fair value down below investment grade [Member]
Investment Holdings [Line Items]
Collateral posted	1
Interest Rate Swap [Member]
Investment Holdings [Line Items]
Unrealized gain (loss) on derivatives	6
Derivative, fixed interest rate	6.09%
Increase in the fair value of derivative	$ 2

Derivative Instruments and Hedging Activities - Fair Values of Companies' Commodity Derivatives (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Derivatives Assets
Impact of netting	$ 84	$ 110
Derivatives Assets [Member]
Derivatives Assets
Fair value of derivative assets	86	165
Impact of netting	(20)	(95)
Net derivatives assets	66	70
Derivatives Assets [Member] \| Other current assets [Member]
Derivatives Assets
Fair value of derivative assets	64	139
Derivatives Assets [Member] \| Other deferred charges and non-current assets [Member]
Derivatives Assets
Fair value of derivative assets	22	26
Derivatives Liabilities [Member]
Derivatives Liabilities
Fair value of derivative liabilities	176	414
Impact of netting	(104)	(205)
Net derivatives liabilities	72	209
Derivatives Liabilities [Member] \| Fair value of derivative liabilities, Current [Member]
Derivatives Liabilities
Fair value of derivative liabilities	122	331
Derivatives Liabilities [Member] \| Fair value of derivative liabilities, Long-term [Member]
Derivatives Liabilities
Fair value of derivative liabilities	54	83
CECONY [Member]
Derivatives Assets
Impact of netting	47	46
CECONY [Member] \| Derivatives Assets [Member]
Derivatives Assets
Fair value of derivative assets	27	30
Impact of netting	3	(6)
Net derivatives assets	30	24
CECONY [Member] \| Derivatives Assets [Member] \| Other current assets [Member]
Derivatives Assets
Fair value of derivative assets	18	16
CECONY [Member] \| Derivatives Assets [Member] \| Other deferred charges and non-current assets [Member]
Derivatives Assets
Fair value of derivative assets	9	14
CECONY [Member] \| Derivatives Liabilities [Member]
Derivatives Liabilities
Fair value of derivative liabilities	83	175
Impact of netting	(44)	(53)
Net derivatives liabilities	39	122
CECONY [Member] \| Derivatives Liabilities [Member] \| Fair value of derivative liabilities, Current [Member]
Derivatives Liabilities
Fair value of derivative liabilities	58	127
CECONY [Member] \| Derivatives Liabilities [Member] \| Fair value of derivative liabilities, Long-term [Member]
Derivatives Liabilities
Fair value of derivative liabilities	$ 25	$ 48

Derivative Instruments and Hedging Activities - Changes in Fair Values of Commodity Derivatives (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	$ (1)	$ (4)
Total deferred gains/ (losses)	(108)	(210)
Net deferred gains/ (losses)	(109)	(214)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(70)	(126)
Deferred derivative gains, Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	(1)
Total deferred gains/ (losses)		(3)
Regulatory liabilities, Long-term [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)		(1)
Deferred derivative losses, Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	95	26
Recoverable energy costs, Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	(220)	(247)
Regulatory assets, Long-term [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	17	11
Purchased power expense [Member]
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(54)	(78)
Gas purchased for resale [Member]
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(5)	(18)
Non-utility revenue [Member]
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(11)	(30)
CECONY [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	(1)	(3)
Total deferred gains/ (losses)	(88)	(170)
Net deferred gains/ (losses)	(89)	(173)
CECONY [Member] \| Deferred derivative gains, Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	(1)
Total deferred gains/ (losses)		(2)
CECONY [Member] \| Regulatory liabilities, Long-term [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)		(1)
CECONY [Member] \| Deferred derivative losses, Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	80	11
CECONY [Member] \| Recoverable energy costs, Current [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	(192)	(185)
CECONY [Member] \| Regulatory assets, Long-term [Member]
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/ (losses)	$ 24	$ 4

The amount of net gains and losses recognized in income during the period on derivative instruments designated and qualifying as hedging instruments in fair value hedges and related hedged items designated and qualifying in fair value hedges, on derivative instruments designated and qualifying as hedging instruments in cash flow hedges, and on derivative instruments not designated as hedging instruments.

+ References+ Details

Derivative Instruments and Hedging Activities - Number of Derivative Contracts by Commodity Type (Detail)	12 Months Ended
	Dec. 31, 2012 MWh MW Contract
Electric Derivatives [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	496
Mwhs	15,761,464
Number of Capacity Contracts	59
MWs	11,668
Electric Derivatives [Member] \| CECONY [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	97
Mwhs	3,565,325
Number of Capacity Contracts
MWs
Gas Derivatives [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	592
Dths	84,706,809
Number of Capacity Contracts	1,147
Gas Derivatives [Member] \| CECONY [Member]
Derivatives, Fair Value [Line Items]
Number of Contracts	484
Dths	79,460,000
Number of Capacity Contracts	581

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	Dec. 31, 2012
Derivatives, Fair Value [Line Items]
Aggregate fair value - net liabilities	$ 52
Collateral posted
Additional Collateral Required Due To Loss Of Unsecured Credit [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	24
Additional collateral	4
Additional collateral aggregate fair value down below investment grade [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	24
Additional collateral	77
CECONY [Member]
Derivatives, Fair Value [Line Items]
Aggregate fair value - net liabilities	39
Collateral posted
CECONY [Member] \| Additional Collateral Required Due To Loss Of Unsecured Credit [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	10
Additional collateral	4
CECONY [Member] \| Additional collateral aggregate fair value down below investment grade [Member]
Derivatives, Fair Value [Line Items]
Collateral posted	1
Additional collateral	$ 43

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended		12 Months Ended				12 Months Ended				12 Months Ended				12 Months Ended			12 Months Ended			12 Months Ended		12 Months Ended							12 Months Ended				12 Months Ended				12 Months Ended					12 Months Ended		12 Months Ended			12 Months Ended					12 Months Ended				12 Months Ended		12 Months Ended		12 Months Ended		12 Months Ended		12 Months Ended			12 Months Ended					12 Months Ended				12 Months Ended		12 Months Ended		12 Months Ended			12 Months Ended		12 Months Ended							12 Months Ended				12 Months Ended			12 Months Ended			12 Months Ended		12 Months Ended
	Dec. 31, 2011	Dec. 31, 2012 Con Edison [Member]	Dec. 31, 2011 CECONY [Member]	Dec. 31, 2012 CECONY [Member]	Dec. 31, 2011 Commodity [Member]	Dec. 31, 2012 Commodity [Member] Con Edison [Member]	Dec. 31, 2012 Commodity [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Commodity [Member] CECONY [Member]	Dec. 31, 2011 Commodity [Member] CECONY [Member]	Dec. 31, 2012 Commodity [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2012 Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2011 Other assets [Member]	Dec. 31, 2012 Other assets [Member] Con Edison [Member]	Dec. 31, 2012 Other assets [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Other assets [Member] CECONY [Member]	Dec. 31, 2011 Other assets [Member] CECONY [Member]	Dec. 31, 2012 Other assets [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2011 Interest rate contract [Member]	Dec. 31, 2012 Interest rate contract [Member] Con Edison [Member]	Dec. 31, 2012 Interest rate contract [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Interest rate contract [Member] CECONY [Member]	Dec. 31, 2012 Interest rate contract [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2011 Level 1 [Member]	Dec. 31, 2012 Level 1 [Member] Con Edison [Member]	Dec. 31, 2012 Level 1 [Member] CECONY [Member]	Dec. 31, 2011 Level 1 [Member] CECONY [Member]	Dec. 31, 2011 Level 1 [Member] Commodity [Member]	Dec. 31, 2012 Level 1 [Member] Commodity [Member] Con Edison [Member]	Dec. 31, 2012 Level 1 [Member] Commodity [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 1 [Member] Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Level 1 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2011 Level 1 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2012 Level 1 [Member] Commodity [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 1 [Member] Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2011 Level 1 [Member] Other assets [Member]	Dec. 31, 2012 Level 1 [Member] Other assets [Member] Con Edison [Member]	Dec. 31, 2012 Level 1 [Member] Other assets [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 1 [Member] Other assets [Member] CECONY [Member]	Dec. 31, 2011 Level 1 [Member] Other assets [Member] CECONY [Member]	Dec. 31, 2012 Level 1 [Member] Other assets [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 1 [Member] Interest rate contract [Member] Con Edison [Member]	Dec. 31, 2012 Level 1 [Member] Interest rate contract [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Level 1 [Member] Interest rate contract [Member] CECONY [Member]	Dec. 31, 2012 Level 1 [Member] Interest rate contract [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2011 Level 2 [Member]	Dec. 31, 2012 Level 2 [Member] Con Edison [Member]	Dec. 31, 2011 Level 2 [Member] CECONY [Member]	Dec. 31, 2012 Level 2 [Member] CECONY [Member]	Dec. 31, 2011 Level 2 [Member] Commodity [Member]	Dec. 31, 2012 Level 2 [Member] Commodity [Member] Con Edison [Member]	Dec. 31, 2012 Level 2 [Member] Commodity [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 2 [Member] Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Level 2 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2011 Level 2 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2012 Level 2 [Member] Commodity [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 2 [Member] Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Level 2 [Member] Other assets [Member] Con Edison [Member]	Dec. 31, 2012 Level 2 [Member] Other assets [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 2 [Member] Other assets [Member] CECONY [Member]	Dec. 31, 2012 Level 2 [Member] Other assets [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 2 [Member] Interest rate contract [Member] Con Edison [Member]	Dec. 31, 2012 Level 2 [Member] Interest rate contract [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Level 2 [Member] Interest rate contract [Member] CECONY [Member]	Dec. 31, 2012 Level 2 [Member] Interest rate contract [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2011 Level 3 [Member]	Dec. 31, 2012 Level 3 [Member] Con Edison [Member]	Dec. 31, 2011 Level 3 [Member] CECONY [Member]	Dec. 31, 2012 Level 3 [Member] CECONY [Member]	Dec. 31, 2011 Level 3 [Member] Commodity [Member]	Dec. 31, 2012 Level 3 [Member] Commodity [Member] Con Edison [Member]	Dec. 31, 2012 Level 3 [Member] Commodity [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 3 [Member] Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Level 3 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2011 Level 3 [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2012 Level 3 [Member] Commodity [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2012 Level 3 [Member] Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2011 Level 3 [Member] Other assets [Member]	Dec. 31, 2012 Level 3 [Member] Other assets [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2011 Level 3 [Member] Other assets [Member] CECONY [Member]	Dec. 31, 2012 Level 3 [Member] Other assets [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2011 Level 3 [Member] Interest rate contract [Member]	Dec. 31, 2012 Level 3 [Member] Interest rate contract [Member] Con Edison [Member]	Dec. 31, 2012 Level 3 [Member] Interest rate contract [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Level 3 [Member] Interest rate contract [Member] CECONY [Member]	Dec. 31, 2012 Level 3 [Member] Interest rate contract [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2011 Netting Adjustments [Member]	Dec. 31, 2012 Netting Adjustments [Member] Con Edison [Member]	Dec. 31, 2012 Netting Adjustments [Member] CECONY [Member]	Dec. 31, 2011 Netting Adjustments [Member] CECONY [Member]	Dec. 31, 2011 Netting Adjustments [Member] Commodity [Member]	Dec. 31, 2012 Netting Adjustments [Member] Commodity [Member] Con Edison [Member]	Dec. 31, 2012 Netting Adjustments [Member] Commodity [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Netting Adjustments [Member] Commodity [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Netting Adjustments [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2011 Netting Adjustments [Member] Commodity [Member] CECONY [Member]	Dec. 31, 2012 Netting Adjustments [Member] Commodity [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2012 Netting Adjustments [Member] Commodity [Member] CECONY [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Netting Adjustments [Member] Other assets [Member] Con Edison [Member]	Dec. 31, 2012 Netting Adjustments [Member] Other assets [Member] Con Edison [Member] Derivatives Assets [Member]	Dec. 31, 2012 Netting Adjustments [Member] Other assets [Member] CECONY [Member] Derivatives Assets [Member]	Dec. 31, 2012 Netting Adjustments [Member] Interest rate contract [Member] Con Edison [Member]	Dec. 31, 2012 Netting Adjustments [Member] Interest rate contract [Member] Con Edison [Member] Derivatives Liabilities [Member]	Dec. 31, 2012 Netting Adjustments [Member] Interest rate contract [Member] CECONY [Member]	Dec. 31, 2012 Netting Adjustments [Member] Interest rate contract [Member] CECONY [Member] Derivatives Liabilities [Member]
Derivative assets:
Derivative assets					$ 70		$ 66			$ 24	$ 30		$ 175	$ 213	$ 213	$ 197	$ 166	$ 197										$ 3								$ 76	$ 106	$ 106	$ 99	$ 76	$ 99									$ 64		$ 43			$ 8	$ 8		$ 107	$ 2	$ 98	$ 3									$ 87		$ 33			$ 11	$ 10		$ 99	$ 105	$ 90	$ 95										$ (84)		$ (10)			$ 5	$ 12
Transfer in	32		31					24				18			105			95			8										9				9											26		25					13				9		105		95		8			6		6					2
Transfer out	32		31					24				18			(105)			(95)			8										2															6		6					11				9									26		25					11				9		(105)		(95)			8
Total Assets	245	279	190	227		66			30															79	106	99	76																			64	150	8	106		43			8												186	33	101	10		33			10													(84)	(10)	12	5		(10)			12
Derivative liabilities:
Derivative liabilities	209		122		209	72		72	39	122		39							8	6	6			12			4	12	12		5	12	4		3											242		141		222	116		114	62	122		62					6	(2)			149		18		169	38		47		37		9					8		8			(194)			(41)	(194)	(94)		(94)	(35)	(41)		(35)
Transfer in	32		31					24				18			105			95			8										9				9											26		25					13				9		105		95		8			6		6					2
Total Liabilities	217	78	122	39																				12	12	12	4																			242	122	141	62																	157	38	18																			(194)	(94)	(35)	(41)
Transfer out	$ (32)		$ (31)					$ (24)				$ (18)			$ 105			$ 95			$ (8)										$ (2)															$ (6)		$ (6)					$ (11)				$ (9)									$ (26)		$ (25)					$ (11)				$ (9)		$ 105		$ 95			$ (8)

Fair values as of the balance sheet date of all assets resulting from contracts that meet the criteria of being accounted for as derivative instruments, net of the effects of master netting arrangements.

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Fair values as of the balance sheet date of all liabilities resulting from contracts that meet the criteria of being accounted for as derivative instruments, net of the effects of master netting arrangements.

+ References+ Details

Fair Value Measurements - Schedule of Commodity Derivatives (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012
Electricity Swaps [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
Electricity Wholesale Contract [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
Standard Offer Capacity Agreements [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
Transmission Congestion Contracts / Financial Transmission Rights [Member]
Financial Instruments [Line Items]
Valuation Techniques	Discounted Cash Flow
Minimum [Member] \| Forward price escalator [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	0.00%
Minimum [Member] \| Present value factor [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	1.66%
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%
Minimum [Member] \| Discount to adjust auction prices for historical monthly realized settlements [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	8.50%
Minimum [Member] \| Forward Energy Prices And Zonal Losses [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	$ 0.01
Minimum [Member] \| Forward prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	28
Minimum [Member] \| Forward Prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	29
Minimum [Member] \| New Jersey solar renewable energy credit [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	90
Minimum [Member] \| Forward capacity prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	166
Maximum [Member] \| Forward price escalator [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	3.00%
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%
Maximum [Member] \| Discount to adjust auction prices for historical monthly realized settlements [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	31.00%
Maximum [Member] \| Forward Energy Prices And Zonal Losses [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	12.00
Maximum [Member] \| Forward prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	82
Maximum [Member] \| Forward Prices [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range	48
Level 3 [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	(5)
Level 3 [Member] \| Electricity Swaps [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	(5)
Level 3 [Member] \| Electricity Wholesale Contract [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	(1)
Level 3 [Member] \| Standard Offer Capacity Agreements [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	(12)
Level 3 [Member] \| Transmission Congestion Contracts / Financial Transmission Rights [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	13
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%
CECONY [Member] \| Minimum [Member] \| Discount to adjust auction prices for historical monthly realized settlements [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	8.50%
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%
CECONY [Member] \| Maximum [Member] \| Discount to adjust auction prices for historical monthly realized settlements [Member]
Financial Instruments [Line Items]
Unobservable Inputs Range in Percentage	31.00%
CECONY [Member] \| Level 3 [Member] \| Transmission Congestion Contracts [Member]
Financial Instruments [Line Items]
Fair Value of commodity derivatives	$ 10

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	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ 29	$ 3
Included in Earnings	(110)	(116)
Included in Regulatory Assets and Liabilities	19	20
Purchases	22	32
Issuances
Sales
Settlements	123	70
Transfer In/Out of Level 3	(88)	20
Ending Balance	(5)	29
Commodity [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	(62)	(88)
Included in Earnings	(112)	(113)
Included in Regulatory Assets and Liabilities	16	20
Purchases	22	32
Issuances
Sales
Settlements	122	67
Transfer In/Out of Level 3	9	20
Ending Balance	(5)	(62)
Interest rate contract [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	(8)	(10)
Included in Earnings	(1)	(3)
Included in Regulatory Assets and Liabilities		2
Purchases
Issuances
Sales
Settlements	1	3
Transfer In/Out of Level 3	8
Ending Balance		(8)
Other assets [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	99	101
Included in Earnings	3
Included in Regulatory Assets and Liabilities	3	(2)
Issuances
Sales
Settlements
Transfer In/Out of Level 3	(105)
Ending Balance		99
CECONY [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	83	66
Included in Earnings	(29)	(21)
Included in Regulatory Assets and Liabilities	10	(2)
Purchases	18	19
Issuances
Sales
Settlements	14	2
Transfer In/Out of Level 3	(86)	19
Ending Balance	10	83
CECONY [Member] \| Commodity [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	(7)	(26)
Included in Earnings	(32)	(21)
Included in Regulatory Assets and Liabilities	8
Purchases	18	19
Issuances
Sales
Settlements	14	2
Transfer In/Out of Level 3	9	19
Ending Balance	10	(7)
CECONY [Member] \| Other assets [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Beginning Balance	90	92
Included in Earnings	3
Included in Regulatory Assets and Liabilities	2	(2)
Purchases
Issuances
Sales
Settlements
Transfer In/Out of Level 3	(95)
Ending Balance		$ 90

Fair Value Measurements - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative assets	$ 12
Gains (loss) on Level 3 energy derivative liabilities		33
Loss on Level 3 energy derivative assets for purchased power costs	46
Gain (loss) on Level 3 energy derivative liabilities for purchased power costs		29
Fair value, assets measured on recurring basis, change in unrealized gain (loss) included in other income	12	33
Fair value, assets measured on recurring basis, change in unrealized gain (loss) included in purchased power costs	$ 46	$ 15

Variable Interest Entities - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	1 Months Ended	12 Months Ended
	Aug. 31, 2011	Dec. 31, 2012
Solar energy generation project cost		$ 90
Operation commenced date	Aug. 01, 2011
Assets related to Pilesgrove		24
Additional financing obligation		$ 24

Asset Retirement Obligations - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Related regulatory liabilities	$ 503	$ 448
Asset retirement obligations	158	145
Reduction of related regulatory liabilities	13	7
Change in estimated cash flows	24
Change in accretion expense	6
Offset in part by liabilities settled	17
CECONY [Member]
Related regulatory liabilities	$ 420	$ 372

The carrying amount of a liability for an asset retirement obligation. An asset retirement obligation is a legal obligation associated with the disposal or retirement of a tangible long-lived asset that results from the acquisition, construction or development, or the normal operations of a long-lived asset, except for certain obligations of lessees.

+ References+ Details