Document and Entity Information	6 Months Ended
Document and Entity Information	Jun. 30, 2010	Jul. 30, 2010
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2010
Document Fiscal Year Focus	2010
Document Fiscal Period Focus	Q2
Trading Symbol	ED
Entity Registrant Name	CONSOLIDATED EDISON INC
Entity Central Index Key	0001047862
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		282,632,105
CONSOLIDATED EDISON CO OF NEW YORK INC [Member]
Entity Registrant Name	CONSOLIDATED EDISON CO OF NEW YORK INC
Entity Central Index Key	0000023632
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

Consolidated Income Statement (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2010	Jun. 30, 2009	Jun. 30, 2010	Jun. 30, 2009
OPERATING REVENUES
Electric	$ 2,256	$ 1,955	$ 4,145	$ 3,758
Gas	274	334	1,047	1,222
Steam	89	113	396	444
Non-utility	398	443	890	845
TOTAL OPERATING REVENUES	3,017	2,845	6,478	6,269
OPERATING EXPENSES
Purchased power	1,140	1,065	2,283	2,205
Fuel	87	86	237	321
Gas purchased for resale	67	136	410	633
Other operations and maintenance	678	622	1,379	1,203
Depreciation and amortization	211	197	415	389
Taxes, other than income taxes	405	367	833	727
TOTAL OPERATING EXPENSES	2,588	2,473	5,557	5,478
OPERATING INCOME	429	372	921	791
OTHER INCOME (DEDUCTIONS)
Investment and other income	14	18	21	21
Allowance for equity funds used during construction	4	3	9	5
Other deductions	(6)	(5)	(9)	(8)
TOTAL OTHER INCOME (DEDUCTIONS)	12	16	21	18
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	441	388	942	809
INTEREST EXPENSE
Interest on long-term debt	148	151	298	293
Other interest	4	6	6	10
Allowance for borrowed funds used during construction	(3)	(2)	(5)	(4)
NET INTEREST EXPENSE	149	155	299	299
INCOME BEFORE INCOME TAX EXPENSE	292	233	643	510
INCOME TAX EXPENSE	106	80	228	174
NET INCOME	186	153	415	336
Preferred stock dividend requirements	(3)	(3)	(6)	(6)
NET INCOME FOR COMMON STOCK	183	150	409	330
Net income for common stock per common share - basic	$ 0.65	$ 0.55	$ 1.45	$ 1.2
Net income for common stock per common share - diluted	$ 0.64	$ 0.55	$ 1.44	$ 1.2
DIVIDENDS DECLARED PER SHARE OF COMMON STOCK	$ 0.595	$ 0.59	$ 1.19	$ 1.18
AVERAGE NUMBER OF SHARES OUTSTANDING - BASIC (IN MILLIONS)	282.0	274.5	281.7	274.2
AVERAGE NUMBER OF SHARES OUTSTANDING - DILUTED (IN MILLIONS)	283.5	275.3	283.2	275.0
CECONY [Member]
OPERATING REVENUES
Electric	2,104	1,812	3,832	3,469
Gas	239	295	922	1,077
Steam	89	113	396	444
TOTAL OPERATING REVENUES	2,432	2,220	5,150	4,990
OPERATING EXPENSES
Purchased power	787	609	1,339	1,256
Fuel	87	86	237	321
Gas purchased for resale	51	114	345	542
Other operations and maintenance	588	532	1,195	1,033
Depreciation and amortization	196	185	388	366
Taxes, other than income taxes	389	354	800	697
TOTAL OPERATING EXPENSES	2,098	1,880	4,304	4,215
OPERATING INCOME	334	340	846	775
OTHER INCOME (DEDUCTIONS)
Investment and other income	14	12	18	15
Allowance for equity funds used during construction	4	3	8	5
Other deductions	(6)	(4)	(9)	(7)
TOTAL OTHER INCOME (DEDUCTIONS)	12	11	17	13
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	346	351	863	788
INTEREST EXPENSE
Interest on long-term debt	133	137	268	265
Other interest	5	5	8	7
Allowance for borrowed funds used during construction	(2)	(2)	(4)	(3)
NET INTEREST EXPENSE	136	140	272	269
INCOME BEFORE INCOME TAX EXPENSE	210	211	591	519
INCOME TAX EXPENSE	72	72	207	180
NET INCOME	138	139	384	339
Preferred stock dividend requirements	(3)	(3)	(6)	(6)
NET INCOME FOR COMMON STOCK	$ 135	$ 136	$ 378	$ 333

Consolidated Statement of Cash Flows (USD $) In Millions, unless otherwise specified	6 Months Ended
	Jun. 30, 2010	Jun. 30, 2009
OPERATING ACTIVITIES
Net Income	$ 415	$ 336
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	415	389
Deferred income taxes	46	159
Rate case amortization and accruals	2	(13)
Common equity component of allowance for funds used during construction	(9)	(5)
Net derivative (gains)/losses	(2)	26
Other non-cash items (net)	39	(7)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	(28)	160
Materials and supplies, including fuel oil and gas in storage	27	159
Other receivables and other current assets	79	(68)
Prepayments		522
Recoverable energy costs		128
Accounts payable	(79)	(157)
Pensions and retiree benefits	49	5
Accrued taxes	(7)	(28)
Accrued interest	(3)	16
Deferred charges, deferred derivative losses, noncurrent assets and other regulatory assets	(319)	(114)
Deferred credits and other regulatory liabilities	111	(19)
Other assets	(7)	(1)
Other liabilities	66	(45)
NET CASH FLOWS FROM OPERATING ACTIVITIES	795	1,443
INVESTING ACTIVITIES
Utility construction expenditures	(946)	(1,034)
Cost of removal less salvage	(66)	(87)
Non-utility construction expenditures	(4)	(3)
Common equity component of allowance for funds used during construction	9	5
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,007)	(1,119)
FINANCING ACTIVITIES
Net (payments of)/proceeds from short-term debt	153	(263)
Issuance of long-term debt	700	750
Retirement of long-term debt	(426)	(278)
Issuance of common stock	25	15
Debt issuance costs	(5)	(5)
Common stock dividends	(311)	(300)
Preferred stock dividends	(6)	(6)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	130	(87)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(82)	237
BALANCE AT BEGINNING OF PERIOD	260	74
BALANCE AT END OF PERIOD	178	311
Cash paid during the period for:
Interest	295	270
Income taxes	157	7
CECONY [Member]
OPERATING ACTIVITIES
Net Income	384	339
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	388	366
Deferred income taxes	56	151
Rate case amortization and accruals	2	(13)
Common equity component of allowance for funds used during construction	(8)	(5)
Other non-cash items (net)	14	(52)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers, less allowance for uncollectibles	(21)	144
Materials and supplies, including fuel oil and gas in storage	14	129
Other receivables and other current assets	58	71
Prepayments	2	463
Recoverable energy costs		148
Accounts payable	(75)	(242)
Pensions and retiree benefits	22	(16)
Accrued taxes	2	(16)
Accrued interest	(4)	13
Deferred charges, deferred derivative losses, noncurrent assets and other regulatory assets	(271)	(63)
Deferred credits and other regulatory liabilities	97	(45)
Other liabilities	77	(45)
NET CASH FLOWS FROM OPERATING ACTIVITIES	737	1,327
INVESTING ACTIVITIES
Utility construction expenditures	(895)	(992)
Cost of removal less salvage	(65)	(85)
Common equity component of allowance for funds used during construction	8	5
Loan to affiliate		113
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(952)	(959)
FINANCING ACTIVITIES
Net (payments of)/proceeds from short-term debt	66	(253)
Issuance of long-term debt	700	750
Retirement of long-term debt	(325)	(275)
Debt issuance costs	(5)	(5)
Capital contribution by parent	24
Common stock dividends	(335)	(326)
Preferred stock dividends	(6)	(6)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	119	(115)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(96)	253
BALANCE AT BEGINNING OF PERIOD	131	37
BALANCE AT END OF PERIOD	35	290
Cash paid during the period for:
Interest	265	244
Income taxes	$ 137	$ 15

Consolidated Balance Sheet (USD $) In Millions, unless otherwise specified	Jun. 30, 2010	Dec. 31, 2009
CURRENT ASSETS
Cash and temporary cash investments	$ 178	$ 260
Accounts receivable - customers, less allowance for uncollectible accounts	1,075	1,047
Accrued unbilled revenue	634	579
Other receivables, less allowance for uncollectible accounts	408	379
Fuel oil, gas in storage, materials and supplies, at average cost	328	355
Prepayments	131	131
Regulatory Assets	229	201
Revenue decoupling mechanism receivable	23	117
Other current assets	152	174
TOTAL CURRENT ASSETS	3,158	3,243
INVESTMENTS	402	385
UTILITY PLANT AT ORIGINAL COST
Electric	19,218	18,645
Gas	4,144	3,983
Steam	1,967	1,935
General	1,875	1,866
TOTAL	27,204	26,429
Less: Accumulated depreciation	5,606	5,412
Net	21,598	21,017
Construction work in progress	1,474	1,422
NET UTILITY PLANT	23,072	22,439
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	22	19
Construction work in progress	3	6
NET PLANT	23,097	22,464
OTHER NONCURRENT ASSETS
Goodwill	420	416
Intangible assets, less accumulated amortization of $3 and $2 in 2010 and 2009, respectively	3	4
Regulatory assets	7,026	7,103
Other deferred charges and noncurrent assets	283	258
TOTAL OTHER NONCURRENT ASSETS	7,732	7,781
TOTAL ASSETS	34,389	33,873
CURRENT LIABILITIES
Long-term debt due within one year	305	731
Notes payable	153
Accounts payable	1,094	1,173
Customer deposits	279	274
Accrued taxes	44	51
Accrued interest	153	156
Accrued wages	90	91
Fair value of derivative liabilities	160	114
Other current liabilities	397	362
TOTAL CURRENT LIABILITIES	2,675	2,952
NONCURRENT LIABILITIES
Obligations under capital leases	10	14
Provision for injuries and damages	172	168
Pensions and retiree benefits	3,012	3,363
Superfund and other environmental costs	236	212
Asset retirement obligations	125	122
Fair value of derivative liabilities	137	131
Other noncurrent liabilities	100	108
TOTAL NONCURRENT LIABILITIES	3,792	4,118
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	5,771	5,597
Regulatory liabilities	982	858
Other deferred credits	24	32
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	6,777	6,487
LONG-TERM DEBT	10,552	9,854
SHAREHOLDER'S EQUITY
Common shareholder's equity (See Statement of Shareholder's Equity)	10,380	10,249
Preferred stock	213	213
TOTAL SHAREHOLDER'S EQUITY	10,593	10,462
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	34,389	33,873
CECONY [Member]
CURRENT ASSETS
Cash and temporary cash investments	35	131
Accounts receivable - customers, less allowance for uncollectible accounts	925	904
Accrued unbilled revenue	484	413
Other receivables, less allowance for uncollectible accounts	155	134
Accounts receivable from affiliated companies	136	124
Fuel oil, gas in storage, materials and supplies, at average cost	295	310
Prepayments	80	82
Regulatory Assets	164	104
Revenue decoupling mechanism receivable	16	107
Other current assets	75	89
TOTAL CURRENT ASSETS	2,365	2,398
INVESTMENTS	148	126
UTILITY PLANT AT ORIGINAL COST
Electric	18,120	17,570
Gas	3,680	3,537
Steam	1,967	1,935
General	1,714	1,708
TOTAL	25,481	24,750
Less: Accumulated depreciation	5,127	4,947
Net	20,354	19,803
Construction work in progress	1,382	1,334
NET UTILITY PLANT	21,736	21,137
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	8	9
NET PLANT	21,744	21,146
OTHER NONCURRENT ASSETS
Regulatory assets	6,491	6,590
Other deferred charges and noncurrent assets	223	201
TOTAL OTHER NONCURRENT ASSETS	6,714	6,791
TOTAL ASSETS	30,971	30,461
CURRENT LIABILITIES
Long-term debt due within one year	300	625
Notes payable	66
Accounts payable	870	937
Accounts payable to affiliated companies	9	17
Customer deposits	265	259
Accrued taxes	27	41
Accrued taxes to affiliated companies	25	9
Accrued interest	133	137
Accrued wages	84	89
Other current liabilities	426	333
TOTAL CURRENT LIABILITIES	2,205	2,447
NONCURRENT LIABILITIES
Obligations under capital leases	10	14
Provision for injuries and damages	165	160
Pensions and retiree benefits	2,631	2,978
Superfund and other environmental costs	151	159
Asset retirement obligations	125	122
Fair value of derivative liabilities	51	44
Other noncurrent liabilities	95	68
TOTAL NONCURRENT LIABILITIES	3,228	3,545
DEFERRED CREDITS AND REGULATORY LIABILITIES
Deferred income taxes and investment tax credits	5,295	5,139
Regulatory liabilities	859	703
Other deferred credits	21	29
TOTAL DEFERRED CREDITS AND REGULATORY LIABILITIES	6,175	5,871
LONG-TERM DEBT	9,736	9,038
SHAREHOLDER'S EQUITY
Common shareholder's equity (See Statement of Shareholder's Equity)	9,414	9,347
Preferred stock	213	213
TOTAL SHAREHOLDER'S EQUITY	9,627	9,560
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	$ 30,971	$ 30,461

Consolidated Balance Sheet (Parenthetical) (USD $) In Millions, unless otherwise specified	Jun. 30, 2010	Dec. 31, 2009
CONSOLIDATED EDISON INC [Member]
Accounts receivable-customers, allowance for uncollectible accounts	$ 71	$ 70
Other receivables, allowance for uncollectible accounts	6	5
Non-utility property, accumulated depreciation	49	45
Intangible assets, accumulated amortization	3	2
CECONY [Member]
Accounts receivable-customers, allowance for uncollectible accounts	63	63
Other receivables, allowance for uncollectible accounts	5	4
Non-utility property, accumulated depreciation	$ 21	$ 20

Consolidated Statement of Comprehensive Income (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2010	Jun. 30, 2009	Jun. 30, 2010	Jun. 30, 2009
NET INCOME	$ 186	$ 153	$ 415	$ 336
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension plan liability adjustments, net of taxes of $1 and $3 in 2010 and $1 and $2 in 2009, respectively	1	1	4	3
Less: Reclassification adjustment for losses included in net income, net of taxes of $0 in 2010 and 2009		(1)
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	1	2	4	3
COMPREHENSIVE INCOME	187	155	419	339
Preferred stock dividend requirements	(3)	(3)	(6)	(6)
COMPREHENSIVE INCOME FOR COMMON STOCK	$ 184	$ 152	$ 413	$ 333

- Definition

The portion of consolidated profit or loss for the period, net of income taxes, which is attributable to the parent. If the entity does not present consolidated financial statements, the amount of profit or loss for the period, net of income taxes.

+ References+ Details

Consolidated Statement of Comprehensive Income (Parenthetical) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2010	Jun. 30, 2009	Jun. 30, 2010	Jun. 30, 2009
Pension plan liability adjustments, net of taxes	$ 1	$ 1	$ 3	$ 2
Less: Reclassification adjustment for losses included in net income, net of taxes			$ 0	$ 0

Consolidated Statement of Common Shareholders' Equity (USD $) In Millions, except Share data	Total	CONSOLIDATED EDISON INC [Member]	CONSOLIDATED EDISON INC [Member] Common Stock [Member]	CONSOLIDATED EDISON INC [Member] Additional Paid- In Capital [Member]	CONSOLIDATED EDISON INC [Member] Retained Earnings [Member]	CONSOLIDATED EDISON INC [Member] Treasury Stock [Member]	CONSOLIDATED EDISON INC [Member] Capital Stock Expense [Member]	CONSOLIDATED EDISON INC [Member] Accumulated Other Comprehensive Income/(Loss) [Member]	CECONY [Member]	CECONY [Member] Common Stock [Member]	CECONY [Member] Additional Paid- In Capital [Member]	CECONY [Member] Retained Earnings [Member]	CECONY [Member] Treasury Stock [Member]	CECONY [Member] Capital Stock Expense [Member]	CECONY [Member] Accumulated Other Comprehensive Income/(Loss) [Member]
BEGINNING BALANCE at Dec. 31, 2008	$ 9,698	$ 8,991	$ 29	$ 4,112	$ 6,685	$ (1,001)	$ (60)	$ (67)		$ 589	$ 3,664	$ 5,780	$ (962)	$ (60)	$ (20)
BEGINNING BALANCE (in shares) at Dec. 31, 2008			273,721,686			23,210,700				235,488,094
Net Income												200
Net income for common stock	180				180
Common stock dividend to parent	(162)	(163)			(162)							(163)
Cumulative preferred dividends		(3)										(3)
Issuance of common shares-dividend reinvestment and employee stock plans (in shares)			532,533
Issuance of common shares-dividend reinvestment and employee stock plans	20			20
Other comprehensive income	1							1
ENDING BALANCE at Mar. 31, 2009	9,737	9,025	29	4,132	6,703	(1,001)	(60)	(66)		589	3,664	5,814	(962)	(60)	(20)
ENDING BALANCE (in shares) at Mar. 31, 2009			274,254,219			23,210,700				235,488,094
BEGINNING BALANCE at Dec. 31, 2008	9,698					(1,001)	(60)			589	3,664		(962)	(60)	(20)
BEGINNING BALANCE (in shares) at Dec. 31, 2008						23,210,700				235,488,094
Net Income	336								339
Net income for common stock	330								333
Other comprehensive income	3
ENDING BALANCE at Jun. 30, 2009	9,748					(1,001)	(60)			589	3,664		(962)	(60)	(20)
ENDING BALANCE (in shares) at Jun. 30, 2009						23,210,700				235,488,094
BEGINNING BALANCE at Mar. 31, 2009	9,737	9,025	29	4,132	6,703	(1,001)	(60)	(66)		589	3,664	5,814	(962)	(60)	(20)
BEGINNING BALANCE (in shares) at Mar. 31, 2009			274,254,219			23,210,700				235,488,094
Net Income	153	139							139			139
Net income for common stock	150				150				136
Common stock dividend to parent	(162)	(163)			(162)							(163)
Cumulative preferred dividends		(3)										(3)
Issuance of common shares-dividend reinvestment and employee stock plans (in shares)			584,916
Issuance of common shares-dividend reinvestment and employee stock plans	21			21
Other comprehensive income	2							2
ENDING BALANCE at Jun. 30, 2009	9,748	8,998	29	4,153	6,691	(1,001)	(60)	(64)		589	3,664	5,787	(962)	(60)	(20)
ENDING BALANCE (in shares) at Jun. 30, 2009			274,839,135			23,210,700				235,488,094
BEGINNING BALANCE at Dec. 31, 2009	10,249	9,347	30	4,420	6,904	(1,001)	(62)	(42)		589	3,877	5,909	(962)	(62)	(4)
BEGINNING BALANCE (in shares) at Dec. 31, 2009			281,123,741			23,210,700				235,488,094
Net Income		246										246
Net income for common stock	226				226
Capital contribution from parent		12									12
Common stock dividend to parent	167	(167)			167							(167)
Cumulative preferred dividends		(3)										(3)
Issuance of common shares-dividend reinvestment and employee stock plans (in shares)			647,731
Issuance of common shares-dividend reinvestment and employee stock plans	28			28
Other comprehensive income	3							3
ENDING BALANCE at Mar. 31, 2010	10,339	9,435	30	4,448	6,963	(1,001)	(62)	(39)		589	3,889	5,985	(962)	(62)	(4)
ENDING BALANCE (in shares) at Mar. 31, 2010			281,771,472			23,210,700				235,488,094
BEGINNING BALANCE at Dec. 31, 2009	10,249					(1,001)	(62)		9,347	589			(962)	(62)	(4)
BEGINNING BALANCE (in shares) at Dec. 31, 2009						23,210,700				235,488,094
Net Income	415								384
Net income for common stock	409								378
Other comprehensive income	4
ENDING BALANCE at Jun. 30, 2010	10,380					(1,001)	(62)		9,414	589			(962)	(62)	(4)
ENDING BALANCE (in shares) at Jun. 30, 2010						23,210,700				235,488,094
BEGINNING BALANCE at Mar. 31, 2010	10,339	9,435	30	4,448	6,963	(1,001)	(62)	(39)		589	3,889	5,985	(962)	(62)	(4)
BEGINNING BALANCE (in shares) at Mar. 31, 2010			281,771,472			23,210,700				235,488,094
Net Income	186	138							138			138
Net income for common stock	183				183				135
Capital contribution from parent		12									12
Common stock dividend to parent	(168)	(168)			(168)							(168)
Cumulative preferred dividends		(3)										(3)
Issuance of common shares-dividend reinvestment and employee stock plans (in shares)			555,964
Issuance of common shares-dividend reinvestment and employee stock plans	25			25
Other comprehensive income	1							1
ENDING BALANCE at Jun. 30, 2010	$ 10,380	$ 9,414	$ 30	$ 4,473	$ 6,978	$ (1,001)	$ (62)	$ (38)	$ 9,414	$ 589	$ 3,901	$ 5,952	$ (962)	$ (62)	$ (4)
ENDING BALANCE (in shares) at Jun. 30, 2010			282,327,436			23,210,700				235,488,094

General

6 Months Ended

Jun. 30, 2010

Description of Activities of Parent Company

General

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

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

The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies' separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, 2009 (the Form 10-K) and their separate unaudited financial statements (including the combined notes thereto) included in Part I, Item 1 of their combined Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2010 (the First Quarter Form 10-Q). Information in the notes to the consolidated financial statements in the Form 10-K and the First Quarter Form 10-Q referred to in these notes is incorporated by reference herein. The use of terms such as "see" or "refer to" shall be deemed to incorporate by reference into these notes the information to which reference is made.

Certain prior year amounts have been reclassified to conform with the current year presentation. Consistent with current industry practice, the Companies are presenting income tax expense as one item on their consolidated income statements (instead of separate items in the operating income and other income sections of the consolidated income statements).

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

6 Months Ended

Jun. 30, 2010

Summary of Significant Accounting Policies

Note A — Summary of Significant Accounting Policies

Earnings Per Common Share

Reference is made to "Earnings Per Common Share" in Note A to the financial statements included in Item 8 of the Form 10-K. For the three and six months ended June 30, 2010 and 2009, Con Edison's basic and diluted EPS are calculated as follows:


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
*(Millions of Dollars, except per share amounts/Shares in Millions)*	2010		2009		2010		2009
Net income for common stock	$	183	$	150	$	409	$	330
Weighted average common shares outstanding – Basic		282.0		274.5		281.7		274.2
Add: Incremental shares attributable to effect of potentially dilutive securities		1.5		0.8		1.5		0.8
Adjusted weighted average common shares outstanding – Diluted		283.5		275.3		283.2		275.0
Net income for common stock per common share – basic	$	0.65	$	0.55	$	1.45	$	1.20
Net income for common stock per common share – diluted	$	0.64	$	0.55	$	1.44	$	1.20

Regulatory Matters

6 Months Ended

Jun. 30, 2010

Regulatory Matters

Note B — Regulatory Matters

Reference is made to "Accounting Policies" in Note A and "Rate Agreements" in Note B to the financial statements included in Item 8 of the Form 10-K and Note B to the financial statements in Part I, Item 1 of the First Quarter Form 10-Q.

Rate Agreements

O&R — Electric

In July 2010, O&R filed a request with the New York State Public Service Commission (NYSPSC) for an increase in the rates it charges for electric service rendered in New York, effective July 2011, of $61.7 million. The filing reflects a return on common equity of 11 percent and a common equity ratio of 49.9 percent. Among other things, the filing proposes continuation of the current provisions with respect to recovery from customers of the cost of purchased power and with respect to the deferral of differences between actual expenses allocable to the electric business for pensions and other postretirement benefits, environmental, research and developmental cost to the amounts for such costs reflected in electric rates. The filing also includes an alternative proposal for a three-year electric rate plan with annual rate increases of $47.1 million effective July 2011, and $33.2 million effective July 2012 and 2013. The multi-year filing reflects a return on common equity of 11.55 percent.

In May 2010, Rockland Electric Company (a regulated utility subsidiary of O&R) (RECO), the Division of Rate Counsel, Staff of the New Jersey Board of Public Utilities (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.

CECONY — Gas

In May 2010, CECONY, the staff of the NYSPSC and other parties entered into a Joint Proposal, with respect to the company's rates for gas delivery service.

The Joint Proposal, which is subject to NYSPSC approval, covers the three-year period October 2010 through September 2013 and 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.

•

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;

•

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;

•

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 post-retirement benefits and other costs; and

•

in the event the company does 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, implemented on an annual basis, 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 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).

•

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.

•

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.

•

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.

•

Continued collection from gas customers of $32 million on an annual basis subject to potential refund (see "Other Regulatory Matters" below and "Investigation of Contractor Payments" in Note H.

CECONY — Steam

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 is subject to NYSPSC approval, 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 as discussed above with respect to CECONY's gas business 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 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.

•

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.

Other Regulatory Matters

In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures (see "Investigation of Contractor Payments" in Note H). Pursuant to NYSPSC orders, a portion of the company's revenues (effective April 2010, $249 million, $32 million and $6 million on an annual basis for electric, gas and steam service, respectively) is being collected subject to potential refund to customers. At June 30, 2010, the company had collected an estimated $394 million from customers subject to potential refund in connection with this proceeding. The company is unable to estimate the amount, if any, of any such refund and, accordingly, has not established a regulatory liability for a refund.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at June 30, 2010 and December 31, 2009 were comprised of the following items:


	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Regulatory assets
Unrecognized pension and other postretirement costs	$	4,128	$	4,472	$	3,939	$	4,259
Future federal income tax		1,390		1,316		1,316		1,249
Environmental remediation costs		417		388		327		329
Net electric deferrals		177		82		177		82
Surcharge for New York State Assessment		156		138		145		126
Deferred derivative losses – long-term		129		106		93		75
Revenue taxes		129		119		126		116
Pension and other postretirement benefits deferrals		135		101		80		49
Property tax reconciliation		43		85		39		85
O&R transition bond charges		50		55		—		—
World Trade Center restoration costs		36		41		36		41
Workers' compensation		35		37		35		37
Deferred storm costs		49		5		36		—
Other		152		158		142		142
Regulatory assets – long-term		7,026		7,103		6,491		6,590
Deferred derivative losses – current		207		141		164		104
Recoverable energy costs – current		22		60		—		—
Regulatory assets – current		229		201		164		104
Total Regulatory Assets	$	7,255	$	7,304	$	6,655	$	6,694
Regulatory liabilities
Allowance for cost of removal less salvage	$	394	$	371	$	323	$	303
Refundable energy costs		136		147		108		77
Net unbilled revenue deferrals		146		91		146		91
Revenue Decoupling Mechanism over collection		37		—		37		—
New York State tax refund		28		—		28		—
2005-2008 capital expenditure reserve		26		24		26		24
Gain on sale of First Avenue properties		23		23		23		23
Gain on sale of 125th Street Property		13		—		13		—
Rate case amortizations		7		21		7		21
Electric rate case deferral		—		19		—		19
Other		172		162		148		145
Regulatory liabilities		982		858		859		703
Deferred derivative gains – current		3		8		3		8
Total Regulatory Liabilities	$	985	$	866	$	862	$	711

"Net electric deferrals" in June 2010 represent 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, in accordance with CECONY's April 2010 rate plan. At December 2009, "net electric deferrals" represented the remaining unamortized balance of certain regulatory assets and liabilities of CECONY that were combined effective April 1, 2005 and were amortized to income in accordance with CECONY's April 2009 rate plan through March 2010.

Long-Term Debt

6 Months Ended

Jun. 30, 2010

Long-Term Debt

Note C — Long-Term Debt

Reference is made to Note C to the financial statements in Item 8 of the Form 10-K and Note C to the financial statements in Part I, Item 1 of the First Quarter Form 10-Q.

In June 2010, CECONY issued $350 million aggregate principal amount of 4.45 percent debentures, Series 2010 A, due 2020 and $350 million aggregate principal amount of 5.70 percent debentures, Series 2010 B, due 2040. In July 2010, O&R issued a notice to change the method used to determine the interest it is required to pay on its $55 million Series 1994 A tax-exempt debt. The debt (which currently bears a variable rate, determined weekly) is subject to mandatory tender for purchase in August 2010. O&R expects to fund the payment of the purchase price for the debt either from the proceeds of the reoffering of the debt (with a fixed interest rate) or, if O&R determines to have the debt cancelled, the sale of other debt securities.

Short-Term Borrowing

6 Months Ended

Jun. 30, 2010

Short-Term Borrowing

Note D — Short-Term Borrowing

Reference is made to Note D to the financial statements in Item 8 of the Form 10-K and Note D to the financial statements in Part I, Item 1 of the First Quarter Form 10-Q.

At June 30, 2010, Con Edison had $153 million of commercial paper outstanding, $66 million of which was outstanding under CECONY's program. The weighted average interest rate was 0.4 percent for each of Con Edison and CECONY. At December 31, 2009, Con Edison and CECONY had no commercial paper outstanding. At June 30, 2010 and December 31, 2009, no loans were outstanding under the Companies' Credit Agreement and $248 million (including $162 million for CECONY) and $193 million (including $135 million for CECONY) of letters of credit were outstanding under the Credit Agreement, respectively.

Pension Benefits

6 Months Ended

Jun. 30, 2010

Pension Benefits

Note E — Pension Benefits

Reference is made to Note E to the financial statements in Item 8 of the Form 10-K and Note E to the financial statement in Part I, Item 1 of the First Quarter Form 10-Q.

Net Periodic Benefit Cost

The components of the Companies' net periodic benefit costs for the three and six months ended June 30, 2010 and 2009 were as follows:


	For the Three Months Ended June 30,
	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Service cost – including administrative expenses	$	42		$	40		$	39		$	37
Interest cost on projected benefit obligation		139			131			130			123
Expected return on plan assets		(176	)		(173	)		(167	)		(165	)
Amortization of net actuarial loss		106			75			100			68
Amortization of prior service costs		2			2			2			2
NET PERIODIC BENEFIT COST	$	113		$	75		$	104		$	65
Amortization of regulatory asset*		1			1			1			1
TOTAL PERIODIC BENEFIT COST	$	114		$	76		$	105		$	66
Cost capitalized		(37	)		(27	)		(34	)		(25	)
Cost deferred		(33	)		(5	)		(32	)		(3	)
Cost charged to operating expenses	$	44		$	44		$	39		$	38

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


	For the Six Months Ended June 30,
	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Service cost – including administrative expenses	$	84		$	80		$	78		$	74
Interest cost on projected benefit obligation		278			262			260			246
Expected return on plan assets		(352	)		(346	)		(334	)		(330	)
Amortization of net actuarial loss		212			150			200			136
Amortization of prior service costs		4			4			4			4
NET PERIODIC BENEFIT COST	$	226		$	150		$	208		$	130
Amortization of regulatory asset*		1			2			1			2
TOTAL PERIODIC BENEFIT COST	$	227		$	152		$	209		$	132
Cost capitalized		(78	)		(54	)		(73	)		(50	)
Cost deferred		(56	)		(36	)		(53	)		(31	)
Cost charged to operating expenses	$	93		$	62		$	83		$	51

*	Relates to increases in CECONY's pension obligations of $33 million from a 1993 special retirement program (which was fully amortized in March 2009) and $45 million from a 1999 special retirement program.

Expected Contributions

Based on estimates as of December 31, 2009, the Companies are not required under funding regulations and laws to make any contributions to the pension plan during 2010. The Companies' policy is to fund their accounting cost to the extent tax deductible, therefore, Con Edison expects to make discretionary contributions in 2010 of $434 million, including $397 million for CECONY (of which CECONY contributed $279 million in the first six months of 2010). During the first six months of 2009, CECONY contributed $184 million to the pension plan. During the second quarter of 2010, the Companies funded $25 million for the non-qualified supplemental pension plans. The Companies are continuing to monitor changes to funding and tax laws that may impact future pension plan funding requirements.

Other Postretirement Benefits

6 Months Ended

Jun. 30, 2010

Other Postretirement Benefits

Note F — Other Postretirement Benefits

Reference is made to Note F to the financial statements in Item 8 of the Form 10-K and Note F to the financial statements in Part I, Item 1 of the First Quarter Form 10-Q.

Net Periodic Benefit Cost

The components of the Companies' net periodic postretirement benefit costs for the three and six months ended June 30, 2010 and 2009 were as follows:


	For the Three Months Ended June 30,
	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Service cost	$	6		$	5		$	5		$	4
Interest cost on accumulated other postretirement benefit obligation		23			24			20			21
Expected return on plan assets		(22	)		(21	)		(19	)		(20	)
Amortization of net actuarial loss		23			18			21			16
Amortization of prior service cost		(3	)		(3	)		(4	)		(3	)
Amortization of transition obligation		1			1			1			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	28		$	24		$	24		$	19
Cost capitalized		(10	)		(9	)		(8	)		(8	)
Cost deferred		1			—			—			—
Cost charged to operating expenses	$	19		$	15		$	16		$	11


	For the Six Months Ended June 30,
	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Service cost	$	12		$	10		$	10		$	8
Interest cost on accumulated other postretirement benefit obligation		46			48			40			42
Expected return on plan assets		(44	)		(42	)		(38	)		(40	)
Amortization of net actuarial loss		46			36			42			32
Amortization of prior service cost		(6	)		(6	)		(8	)		(6	)
Amortization of transition obligation		2			2			2			2
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	56		$	48		$	48		$	38
Cost capitalized		(20	)		(18	)		(17	)		(15	)
Cost deferred		—			(1	)		(2	)		(2	)
Cost charged to operating expenses	$	36		$	29		$	29		$	21

Health Care Reform

In March 2010, the Patient Protection and Affordable Care Act and the Health Care and Education Reconciliation Act of 2010 became law. The Companies are assessing the impact of these laws. In the first half of 2010, the Companies reduced their deferred tax asset to reflect the laws' repeal, effective 2013, of the deduction for federal income tax purposes of the portion of the cost of an employer's retiree prescription drug coverage for which the employer received a benefit under the Medicare Prescription Drug Improvement and Modernization Act of 2003 (see Note F to the financial statements in Item 8 of the Form 10-K). For CECONY, the reductions in its deferred tax asset of $33 million had no effect on net income because a regulatory asset in a like amount on a pre-tax basis was established to reflect future recovery from customers of the increased cost of its retiree prescription drug coverage resulting from the loss of the tax deduction. For O&R's New York electric and gas services the reductions in their deferred tax assets of $3 million had no effect on net income because a regulatory asset in a like amount on a pre-tax basis was established to reflect future recovery from customers of the increased cost of their retiree prescription drug coverage resulting from the loss of the tax deduction. For RECO and Pike County Light & Power Company (Pike), the reduction in their deferred tax assets of $1 million was taken as a charge to net income. The impact on Con Edison's deferred tax assets for its other businesses was not material to its results of operations.

Environmental Matters

6 Months Ended

Jun. 30, 2010

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 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 June 30, 2010 and December 31, 2009 were as follows:


	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Accrued Liabilities:
Manufactured gas plant sites	$	190	$	164	$	105	$	112
Other Superfund Sites		46		48		46		47
Total	$	236	$	212	$	151	$	159
Regulatory assets	$	417	$	388	$	327	$	329

Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for many 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 will 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.

Insurance recoveries related to Superfund Sites for the three and six months ended June 30, 2010 were immaterial. There were no insurance recoveries received related to Superfund Sites for the three and six months ended June 30, 2009. Environmental remediation costs incurred related to Superfund Sites during the three months ended June 30, 2010 and 2009 were as follows:


	For the Three Months Ended June 30,
	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Remediation costs incurred	$	14	$	24	$	13	$	23


	For the Six Months Ended June 30,
	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Remediation costs incurred	$	23	$	40	$	21	$	39

In 2006, 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 $1.1 billion. In 2007, 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 $115 million. These estimates were based on the assumption that there is contamination at the sites that have not yet been investigated and additional assumptions about these and the other sites regarding the extent of contamination and the type and extent of 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 2008, CECONY estimated that its aggregate undiscounted potential liability for these suits and additional suits that may be brought over the next 15 years is $9 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 June 30, 2010 and December 31, 2009 were as follows:


	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Accrued liability – asbestos suits	$	10	$	10	$	9	$	9
Regulatory assets – asbestos suits	$	10	$	10	$	9	$	9
Accrued liability – workers' compensation	$	110	$	113	$	105	$	108
Regulatory assets – workers' compensation	$	35	$	37	$	35	$	37

Other Material Contingencies

6 Months Ended

Jun. 30, 2010

Other Material Contingencies

Note H — Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately 100 suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for personal injury, property damage and business interruption. The company has not accrued a liability for the suits. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover most of the company's costs, which the company is unable to estimate, but which could be substantial, to satisfy its liability to others in connection with the incident.

Investigation of Contractor Payments

In January 2009, CECONY commenced an internal investigation relating to the arrests of certain employees and retired employees (all of whom have since pleaded guilty) for accepting kickbacks from contractors that performed construction work for the company. The company has retained a law firm, which has retained an accounting firm, to assist in the company's investigation. The company is providing information to governmental authorities, which consider the company to be a victim of unlawful conduct, in connection with their investigation of the arrested employees and contractors. The company has terminated its employment of the arrested employees and its contracts with the contractors (one of which is suing the company for substantial damages claiming wrongful termination). In February 2009, the NYSPSC commenced a proceeding that, among other things, will examine the prudence of certain of the company's expenditures relating to the arrests and consider whether additional expenditures should also be examined (see "Other Regulatory Matters" in Note B). The company, based upon its evaluation of its internal controls for 2009 and previous years, believes that the controls were effective to provide reasonable assurance that its financial statements have been fairly presented, in all material respects, in conformity with generally accepted accounting principles. Because the company's investigation is ongoing, the company is unable to predict the impact of any of the employees' unlawful conduct on the company's internal controls, business, results of operations or financial position.

Permit Non-Compliance and Pollution Discharges

In March 2009, the New York State Department of Environmental Conservation (NYSDEC) issued a proposed administrative Order on Consent to CECONY with respect to non-compliance with certain laws, regulations and permit conditions and discharges of pollutants at the company's steam generating facilities. The proposed order effectively instituted a civil enforcement proceeding against the company. In the proposed order, the NYSDEC is seeking, among other things, the company's agreement to pay a penalty in an amount the NYSDEC did not specify, retain an independent consultant to conduct a comprehensive audit of the company's generating facilities to determine compliance with federal and New York State environmental laws and regulations and recommend best practices, remove all equipment containing polychlorinated biphenyls from the company's steam and electric facilities, remediate polychlorinated biphenyl contamination, install certain wastewater treatment facilities, and comply with additional sampling, monitoring, and training requirements. In March 2010, the NYSDEC issued a revised proposed consent order specifying the amount of penalty the NYSDEC is seeking at $10.8 million. The company will seek to resolve this matter through negotiations with the NYSDEC. It is unable to predict the impact of this matter on the company's operations or the additional costs, which could be substantial, to comply with the requirements resulting from this matter.

In January 2010, the NYSDEC issued a proposed administrative Order on Consent to CECONY relating to discharges of pollutants, reported by the company to the NYSDEC from 2002 through 2009, into the storm sewer system at a property the company owns in the Astoria section of New York on which the company is permitted by the NYSDEC to operate a hazardous waste storage facility. In April 2010, the NYSDEC issued an order, to which CECONY consented, pursuant to which CECONY paid a $1.1 million penalty and undertake a corrective action plan that will require the company to incur an estimated $12 million of capital expenditures.

In June 2010, the NYSDEC issued a proposed consent order relating to the release of oil into the Bronx River resulting from a November 2009 transformer fire at the company's Dunwoodie electric substation. In July 2010, the NYSDEC issued an order, to which CECONY consented, pursuant to which CECONY will pay a penalty and other amounts totaling $0.7 million.

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 $(33) million at June 30, 2010 and $(24) million at December 31, 2009 and is comprised of a $235 million gross investment less $268 million deferred tax liabilities at June 30, 2010 and $235 million gross investment less $259 million of deferred tax liabilities at December 31, 2009.

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

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

Con Edison believes that its LILO transactions have been correctly reported, and has not recorded any reserve with respect to the disallowance of tax losses, or related interest, in connection with its LILO transactions. Con Edison's estimated tax savings, reflected in its financial statements, from the two LILO transactions through June 30, 2010, in the aggregate, was $213 million. If Con Edison were required to repay all or a portion of these amounts, it would also be required to pay interest of up to $71 million net of tax at June 30, 2010.

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

Guarantees

Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled $880 million and $929 million at June 30, 2010 and December 31, 2009, respectively.

A summary, by type (described in Note H to the financial statements in Item 8 of the Form 10-K) and term, of Con Edison's total guarantees at June 30, 2010 is as follows:


Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	*(Millions of Dollars)*
Commodity transactions	$	617	$	9	$	134	$	760
Affordable housing program		4		—		—		4
Intra-company guarantees		30		—		1		31
Other guarantees		65		20		—		85
TOTAL	$	716	$	29	$	135	$	880

Financial Information by Business Segment

6 Months Ended

Jun. 30, 2010

Financial Information by Business Segment

Note I — Financial Information by Business Segment

Reference is made to Note N to the financial statements in Item 8 of the Form 10-K.

The financial data for the business segments are as follows:


	For the Three Months Ended June 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
*(Millions of Dollars)*	2010			2009			2010			2009			2010		2009		2010			2009
CECONY
Electric	$	2,104		$	1,812		$	2		$	3		$	156	$	146	$	319		$	312
Gas		239			295			1			1			25		24		44			46
Steam		89			113			18			18			15		15		(29	)		(18	)
Consolidation adjustments		—			—			(21	)		(22	)		—		—		—			—
Total CECONY	$	2,432		$	2,220		$	—		$	—		$	196	$	185	$	334		$	340
O&R
Electric	$	153		$	144		$	—		$	—		$	8	$	8	$	15		$	10
Gas		35			39			—			—			3		3		(1	)		—
Total O&R	$	188		$	183		$	—		$	—		$	11	$	11	$	14		$	10
Competitive energy businesses	$	406		$	454		$	—		$	(1	)	$	4	$	1	$	81		$	24
Other*		(9	)		(12	)		—			1			—		—		—			(2	)
Total Con Edison	$	3,017		$	2,845		$	—		$	—		$	211	$	197	$	429		$	372

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


	For the Six Months Ended June 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
*(Millions of Dollars)*	2010			2009			2010			2009			2010		2009		2010			2009
CECONY
Electric	$	3,832		$	3,469		$	6		$	6		$	307	$	288	$	514		$	458
Gas		922			1,077			2			2			50		49		259			252
Steam		396			444			36			36			31		29		73			65
Consolidation adjustments		—			—			(44	)		(44	)		—		—		—			—
Total CECONY	$	5,150		$	4,990		$	—		$	—		$	388	$	366	$	846		$	775
O&R
Electric	$	314		$	289		$	—		$	—		$	16	$	15	$	22		$	18
Gas		125			145			—			—			6		6		21			20
Total O&R	$	439		$	434		$	—		$	—		$	22	$	21	$	43		$	38
Competitive energy businesses	$	906		$	867		$	—		$	(3	)	$	5	$	2	$	33		$	(18	)
Other*		(17	)		(22	)		—			3			—		—		(1	)		(4	)
Total Con Edison	$	6,478		$	6,269		$	—		$	—		$	415	$	389	$	921		$	791

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

Derivative Instruments and Hedging Activities

6 Months Ended

Jun. 30, 2010

Derivative Instruments and Hedging Activities

Note J — Derivative Instruments and Hedging Activities

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

Energy Price Hedging

Con Edison's subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, and steam by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. The fair values of these hedges at June 30, 2010 and December 31, 2009 were as follows:


	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Fair value of net derivative assets/(liabilities) – gross	$	(363	)	$	(266	)	$	(223	)	$	(137	)
Impact of netting of cash collateral		194			162			113			87
Fair value of net derivative assets/(liabilities) – net	$	(169	)	$	(104	)	$	(110	)	$	(50	)

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 June 30, 2010, Con Edison and CECONY had $173 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 $116 million with investment-grade counterparties, and $57 million primarily with commodity exchange brokers or independent system operators. CECONY's entire net credit exposure was with commodity exchange brokers.

Economic Hedges

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

The fair values of the Companies' commodity derivatives at June 30, 2010 were:


*(Millions of Dollars)*	Fair Value of Commodity Derivatives(a) Balance Sheet Location	Con Edison			CECONY
Asset Derivatives
Current	Other current assets	$	199		$	12
Long term	Other deferred charges and non-current assets		128			5
Total asset derivatives		$	327		$	17
Impact of netting			(211	)		8
Net asset derivatives		$	116		$	25
Liability Derivatives
Current	Fair value of derivative liabilities	$	479		$	—
Current	Other current liabilities		—			148
Long term	Fair value of derivative liabilities		211			92
Total liability derivatives		$	690		$	240
Impact of netting			(405	)		(105	)
Net liability derivatives		$	285		$	135

(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 value of the Companies' commodity derivatives at December 31, 2009 were:


*(Millions of Dollars)*	Fair Value of Commodity Derivatives(a) Balance Sheet Location	Con Edison			CECONY
Asset Derivatives
Current	Fair value of derivative assets	$	213		$	40
Long term	Other deferred charges and non-current assets		148			19
Total asset derivatives		$	361		$	59
Impact of netting			(231	)		(20	)
Net asset derivatives		$	130		$	39
Liability Derivatives
Current	Fair value of derivative liabilities	$	401		$	110
Long term	Fair value of derivative liabilities		226			86
Total liability derivatives		$	627		$	196
Impact of netting			(393	)		(107	)
Net liability derivatives		$	234		$	89

(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 costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility commissions. See "Recoverable Energy Costs" in Note A to the financial statements in Item 8 of the Form 10-K. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies' consolidated income statements. Con Edison's competitive energy businesses record realized and unrealized gains and losses on their derivative contracts in earnings in the reporting period in which they occur.

The following table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and six months ended June 30, 2010:


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Three Months Ended June 30, 2010
*(Millions of Dollars)*	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	1		$	1
Total deferred gains		$	1		$	1
Current	Other current assets	$	95		$	78
Current	Recoverable energy costs	$	(80	)	$	(67	)
Long term	Regulatory assets	$	51		$	38
Total deferred losses		$	66		$	49
Net deferred losses		$	67		$	50
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(43	)(b)	$	—
	Gas purchased for resale		(11	)		—
	Non-utility revenue		2	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(52	)	$	—

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

(b)	For the three months ended June 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(45) million and $110 million, respectively.


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Six Months Ended June 30, 2010
*(Millions of Dollars)*	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Other current liabilities	$	(5	)	$	(5	)
Total deferred gains		$	(5	)	$	(5	)
Current	Other current assets	$	(66	)	$	(60	)
Current	Recoverable energy costs	$	(135	)	$	(109	)
Long term	Regulatory assets	$	(23	)	$	(18	)
Total deferred losses		$	(224	)	$	(187	)
Net deferred losses		$	(229	)	$	(192	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(106	)	$	—
	Gas purchased for resale		(6	)		—
	Non-utility revenue		17	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(95	)	$	—

(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 six months ended June 30, 2010, Con Edison recorded in non-utility operating revenues an unrealized pre-tax gain/(loss) of $2 million.

The following table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and six months ended June 30, 2009:


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Three Months Ended June 30, 2009
*(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	$	(9	)	$	(9	)
Total deferred gains		$	(9	)	$	(9	)
Current	Deferred derivative losses	$	65		$	66
Current	Recoverable energy costs	$	(122	)	$	(102	)
Long term	Regulatory assets	$	25		$	15
Total deferred losses		$	(32	)	$	(21	)
Net deferred losses		$	(41	)	$	(30	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(144	)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		139	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(6	)	$	—

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

(b)	For the three months ended June 30, 2009, Con Edison recorded in non-utility operating revenues an unrealized pre-tax gain of $31 million.


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Six Months Ended June 30, 2009
*(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	$	(13	)	$	(13	)
Total deferred gains		$	(13	)	$	(13	)
Current	Deferred derivative losses	$	25		$	40
Current	Recoverable energy costs	$	(303	)	$	(259	)
Long term	Regulatory assets	$	(20	)	$	(16	)
Total deferred losses		$	(298	)	$	(235	)
Net deferred losses		$	(311	)	$	(248	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(255	)	$	—
	Gas purchased for resale		2			—
	Non-utility revenue		215	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(38	)	$	—

(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 six months ended June 30, 2009, Con Edison recorded in non-utility operating revenues an unrealized pre-tax loss of $26 million.

As of June 30, 2010, Con Edison had 1,422 contracts, including 677 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	692	17,552,057	45	8,013	685	112,842,500	1,422
CECONY	123	3,703,750	—	—	554	105,250,000	677

(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 June 30, 2010, 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	$	374		$	149
Collateral posted	$	212		$	73	(b)
Additional collateral(c) (downgrade one level from current ratings(d))	$	33		$	27
Additional collateral(c) (downgrade to below investment grade from current ratings(d))	$	301	(e)	$	89

(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 June 30, 2010, would have amounted to an estimated $194 million for Con Edison, including $121 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)	Across the Utilities' energy derivative positions, credit limits for the same counterparties are generally integrated. At June 30, 2010, the Utilities posted combined collateral of $117 million, including an estimated $44 million attributable to O&R.

(c)

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

(d)

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

(e)	Derivative instruments that are net assets have been excluded from the table. At June 30, 2010, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of not more than $20 million.

Interest Rate Swaps

O&R has an interest rate swap related to its Series 1994A Debt. See Note C to the financial statement in Item 8 of the Form 10-K. O&R pays a fixed-rate of 6.09 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at June 30, 2010 was an unrealized loss of $12 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. There was no material change in the fair value of the swap for the three and six months ended June 30, 2010. In the event O&R's credit rating was downgraded to BBB- or lower by Standard & Poor's Rating Services or Baa3 or lower by Moody's Investors Service, the swap counterparty could elect to terminate the agreement and, if it did so, the parties would then be required to settle the transaction.

Fair Value Measurements

6 Months Ended

Jun. 30, 2010

Fair Value Measurements

Note K — Fair Value Measurements

Effective January 1, 2010, the Companies adopted Accounting Standards Update (ASU) No. 2010-06, "Fair Value Measurements and Disclosures (Topic 820): Improving Disclosures about Fair Value Measurements," except as discussed in the following paragraph. This update requires the Companies to disclose significant transfers in and out of Level 1 and Level 2 fair value measurements and describe the reasons for the transfers. The guidance also clarifies level of disaggregation and disclosure requirements about inputs and valuation techniques used to measure fair value for both recurring and nonrecurring fair value measurements and the meaning of a class of assets and liabilities. In addition, the update requires the Companies to present information about purchases, sales, issuances, and settlements on a gross basis in the reconciliation for fair value measurements using significant unobservable inputs (Level 3). This disclosure is effective for fiscal years beginning after December 15, 2010 and for interim periods within those fiscal years.

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. See Note P to the financial statements in Item 8 of the Form 10-K for how the Companies classify fair value balances based on the fair value hierarchy.

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

Assets and liabilities measured at fair value on a recurring basis as of June 30, 2010 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	$	—	$	—	$	69		$	7		$	195		$	5		$	(148	)	$	13		$	116		$	25
Transfers in(5)(6)		—		—		—			—			2			2			—			—			2			2
Transfers out(5)(6)		—		—		(2	)		(2	)		—			—			—			—			(2	)		(2	)
Commodity(1)		—		—		67			5			197			7			(148	)		13			116			25
Other assets(3)		58		58		—			—			94			85			—			—			152			143
Total	$	58	$	58	$	67		$	5		$	291		$	92		$	(148	)	$	13		$	268		$	168
Derivative liabilities:
Commodity	$	6	$	5	$	303		$	173		$	318		$	57		$	(342	)	$	(100	)	$	285		$	135
Transfers in(5)(7)		—		—		20			20			—			—			—			—			20			20
Transfers out(5)(7)		—		—		—			—			(20	)		(20	)		—			—			(20	)		(20	)
Commodity(1)		6		5		323			193			298			37			(342	)		(100	)		285			135
Interest rate contract(2)		—		—		—			—			12			—			—			—			12			—
Total	$	6	$	5	$	323		$	193		$	310		$	37		$	(342	)	$	(100	)	$	297		$	135

(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 J.

(2)	See Note J.

(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 March 31, 2010 to less than one year as of June 30, 2010.

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2009 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	$	3	$	92	$	21	$	201	$	17	$	(166	)	$	(2	)	$	130	$	39
Other assets(3)		36		36		—		—		92		83		—			—			128		119
Total	$	39	$	39	$	92	$	21	$	293	$	100	$	(166	)	$	(2	)	$	258	$	158
Derivative liabilities:
Commodity(1)	$	6	$	1	$	296	$	155	$	260	$	22	$	(328	)	$	(89	)	$	234	$	89
Interest rate contract(2)		—		—		—		—		11		—		—			—			11		—
Total	$	6	$	1	$	296	$	155	$	271	$	22	$	(328	)	$	(89	)	$	245	$	89

(1)

(2)	See Note O to the financial statements in Item 8 of the Form 10-K.

(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.

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


	For the Three Months Ended June 30, 2010
			Total Gains/(Losses)— Realized and Unrealized
*(Millions of Dollars)*	Beginning Balance as of April 1, 2010		Included in Earnings		Included in Regulatory Assets and Liabilities		Purchases, Issuances, Sales and Settlements		Transfer In/Out of Level 3	Ending Balance as of June 30, 2010
Con Edison
Derivatives:
Commodity	(168	)	1		34		14		18	(101	)
Interest rate contract	(11	)	(1	)	(1	)	1		—	(12	)
Other(1)	93		—		1		—		—	94
Total	(86	)	—		34		15		18	(19	)
CECONY
Derivatives:
Commodity	(48	)	(2	)	4		(2	)	18	(30	)
Other(1)	84		—		1		—		—	85
Total	36		(2	)	5		(2	)	18	55

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


	For the Six Months Ended June 30, 2010
			Total Gains/(Losses)— Realized and Unrealized
*(Millions of Dollars)*	Beginning Balance as of January 1, 2010		Included in Earnings		Included in Regulatory Assets and Liabilities		Purchases, Issuances, Sales and Settlements		Transfer In/Out of Level 3	Ending Balance as of June 30, 2010
Con Edison
Derivatives:
Commodity	(59	)	(50	)	(38	)	28		18	(101	)
Interest rate contract	(11	)	(2	)	(1	)	2		—	(12	)
Other(1)	92		—		2		—		—	94
Total	22		(52	)	(37	)	30		18	(19	)
CECONY
Derivatives:
Commodity	(5	)	(7	)	(29	)	(7	)	18	(30	)
Other(1)	83		—		2		—		—	85
Total	78		(7	)	(27	)	(7	)	18	55

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

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and six months ended June 30, 2009 and classified as Level 3 in the fair value hierarchy:


	For the Three Months Ended June 30, 2009
				Total Gains/(Losses)— Realized and Unrealized
*(Millions of Dollars)*	Beginning Balance as of April 1, 2009			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases, Issuances, Sales and Settlements		Transfer In/Out of Level 3		Ending Balance as of June 30, 2009
Con Edison
Derivatives:
Energy	$	(115	)	$	(76	)	$	1		$	105	$	—	$	(85	)
Financial & other		(14	)		—			2			—		—		(12	)
Other		68			5			9			—		—		82
Total	$	(61	)	$	(71	)	$	12		$	105	$	—	$	(15	)
CECONY
Derivatives:
Energy	$	(7	)	$	(5	)	$	(7	)	$	21	$	—	$	2
Other		61			5			8			—		—		74
Total	$	54		$	—		$	1		$	21	$	—	$	76


	For the Six Months Ended June 30, 2009
				Total Gains/(Losses)— Realized and Unrealized
*(Millions of Dollars)*	Beginning Balance as of January 1, 2009			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases, Issuances, Sales and Settlements		Transfer In/Out of Level 3		Ending Balance as of June 30, 2009
Con Edison
Derivatives:
Energy	$	(50	)	$	(105	)	$	(51	)	$	121	$	—	$	(85	)
Financial & other		(15	)		—			3			—		—		(12	)
Other		73			3			6			—		—		82
Total	$	8		$	(102	)	$	(42	)	$	121	$	—	$	(15	)
CECONY
Derivatives:
Energy	$	1		$	(6	)	$	(15	)	$	22	$	—	$	2
Other		65			3			6			—		—		74
Total	$	66		$	(3	)	$	(9	)	$	22	$	—	$	76

For the Utilities, realized gains and losses on Level 3 commodity derivative assets and liabilities are reported as part of purchased power, gas and fuel costs. The Utilities generally recover these costs in accordance with rate provisions approved by the applicable state public utilities commissions. See Note A to the financial statements in Item 8 of the Form 10-K. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations.

For the competitive energy businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($27 million loss and $39 million loss) and purchased power costs ($49 million gain and $1 million loss) on the consolidated income statement for the three months ended June 30, 2010 and 2009, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($33 million gain and $53 million loss) and purchased power costs ($40 million loss and $1 million loss) on the consolidated income statement for the six months ended June 30, 2010 and 2009, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at June 30, 2010 is included in non-utility revenues ($45 million loss) and purchased power costs ($64 million gain) on the consolidated income statement for the three months ended June 30, 2010. For the three months ended June 30, 2009, the change in fair value relating to Level 3 commodity derivative assets and liabilities included in non-utility revenues was an $11 million gain and was immaterial in purchased power costs. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at June 30, 2010 is included in non-utility revenues ($1 million gain) and purchased power costs ($7 million loss) on the consolidated income statement for the six months ended June 30, 2010. For the six months ended June 30, 2009, the change in fair value relating to Level 3 commodity derivative assets and liabilities included in non-utility revenues was a $1 million loss and was immaterial in purchased power costs.

For the Utilities, realized and unrealized gains and losses on Level 3 other assets and liabilities were immaterial for the three months ended June 30, 2010 and a $5 million gain, which is reported in investment and other income on the consolidated income statement, for the three months ended June 30, 2009. Realized and unrealized gains and losses on Level 3 other assets and liabilities were immaterial for the six months ended June 30, 2010 and a $3 million gain, which is reported in investment and other income on the consolidated income statement for the six months ended June 30 2009.

- Definition

This element represents the disclosure related to the fair value measurement of assets and liabilities which includes [financial] instruments measured at fair value that are classified in stockholders' equity. Such assets and liabilities may be measured on a recurring or nonrecurring basis. The disclosures which may be required or desired include: (1) for assets and liabilities measured on a recurring basis, disclosure may include: (a) the fair value measurements at the reporting date; (b) the level within the fair value hierarchy in which the fair value measurements in their entirety fall, segregating fair value measurements using quoted prices in active markets for identical assets or liabilities (Level 1), significant other observable inputs (Level 2), and significant unobservable inputs (Level 3); (c) for fair value measurements using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (i) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets), and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (ii) purchases, sales, issuances, and settlements (net); (iii) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs); (d) the amount of the total gains or losses for the period in subparagraph (c) (i) above included in earnings (or changes in net assets) that are attributable to the change in unrealized gains or losses relating to those assets and liabilities still held at the reporting date and a description of where those unrealized gains or losses are reported in the statement of income (or activities); (e) the valuation technique(s) used to measure fair value and a discussion of changes in valuation techniques, if any, during the period and (2) for assets and liabilities that are measured at fair value on a nonrecurring basis (for example, impaired assets) disclosure may include, in addition to (a) above: (a) the reasons for the fair value measurements recorded; (b) the same as (b) above; (c) for fair value measurements using significant unobservable inputs (Level 3), a description of the inputs and the information used to develop the inputs; and (d) the valuation technique(s) used to measure fair value and a discussion of changes, if any, in the valuation technique(s) used to measure similar assets and/or liabilities in prior periods.

+ References+ Details

Variable Interest Entities

6 Months Ended

Jun. 30, 2010

Variable Interest Entities

Note L — Variable Interest Entities

Reference is made to Notes Q and T to the financial statements in Item 8 of the Form 10-K and Note L to the financial statements in Part I, Item 1 of the First Quarter Form 10-Q.

Effective January 1, 2010, the Companies adopted ASU No. 2009-17, "Consolidations (Topic 810): Improvements to Financial Reporting by Enterprises Involved with 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 accounts of the VIE in the Companies' consolidated financial statements. In the second quarter of 2010, CECONY again requested from 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.), with which CECONY has long-term electricity purchase agreements, the information necessary to determine whether the entity is a VIE and whether CECONY is its primary beneficiary. The information was not made available. CECONY also has a long-term electricity purchase agreement with Astoria Energy, LLC (Astoria Energy). CECONY has determined that Astoria Energy is a VIE, and that CECONY is not its primary beneficiary 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's significant involvement with the entities with which it entered into long-term electricity purchase agreements is CECONY's purchase of energy and capacity under the agreements, as to which CECONY's maximum exposure to the entities is limited pursuant to the agreements. For information about the agreements, see Note I to the financial statements in Item 8 of the Form 10-K.

- Definition

Disclosure of variable interest entities (VIE), including, but not limited to the nature, purpose, size, and activities of the VIE, the carrying amount and classification of consolidated assets that are collateral for the VIE's obligations, lack of recourse if creditors (or beneficial interest holders) of a consolidated VIE have no recourse to the general credit of the primary beneficiary. An enterprise that holds a significant variable interest in a VIE but is not the primary beneficiary may disclose the nature of its involvement with the VIE and when that involvement began, the nature, purpose, size, and activities of the VIE and the enterprise's maximum exposure to loss as a result of its involvement with the VIE.

+ References+ Details

New Financial Accounting Standards	6 Months Ended
New Financial Accounting Standards	Jun. 30, 2010
New Financial Accounting Standards	Note M — New Financial Accounting Standards Reference is made to Note T to the financial statements in Item 8 of the Form 10-K and Note M to the financial statements in Part I, Item 1 of the First Quarter Form 10-Q.

Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2010

Earnings Per Common Share


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
*(Millions of Dollars, except per share amounts/Shares in Millions)*	2010		2009		2010		2009
Net income for common stock	$	183	$	150	$	409	$	330
Weighted average common shares outstanding – Basic		282.0		274.5		281.7		274.2
Add: Incremental shares attributable to effect of potentially dilutive securities		1.5		0.8		1.5		0.8
Adjusted weighted average common shares outstanding – Diluted		283.5		275.3		283.2		275.0
Net income for common stock per common share – basic	$	0.65	$	0.55	$	1.45	$	1.20
Net income for common stock per common share – diluted	$	0.64	$	0.55	$	1.44	$	1.20

Regulatory Matters (Tables)

6 Months Ended

Jun. 30, 2010

Regulatory Assets and Liabilities


	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Regulatory assets
Unrecognized pension and other postretirement costs	$	4,128	$	4,472	$	3,939	$	4,259
Future federal income tax		1,390		1,316		1,316		1,249
Environmental remediation costs		417		388		327		329
Net electric deferrals		177		82		177		82
Surcharge for New York State Assessment		156		138		145		126
Deferred derivative losses – long-term		129		106		93		75
Revenue taxes		129		119		126		116
Pension and other postretirement benefits deferrals		135		101		80		49
Property tax reconciliation		43		85		39		85
O&R transition bond charges		50		55		—		—
World Trade Center restoration costs		36		41		36		41
Workers' compensation		35		37		35		37
Deferred storm costs		49		5		36		—
Other		152		158		142		142
Regulatory assets – long-term		7,026		7,103		6,491		6,590
Deferred derivative losses – current		207		141		164		104
Recoverable energy costs – current		22		60		—		—
Regulatory assets – current		229		201		164		104
Total Regulatory Assets	$	7,255	$	7,304	$	6,655	$	6,694
Regulatory liabilities
Allowance for cost of removal less salvage	$	394	$	371	$	323	$	303
Refundable energy costs		136		147		108		77
Net unbilled revenue deferrals		146		91		146		91
Revenue Decoupling Mechanism over collection		37		—		37		—
New York State tax refund		28		—		28		—
2005-2008 capital expenditure reserve		26		24		26		24
Gain on sale of First Avenue properties		23		23		23		23
Gain on sale of 125th Street Property		13		—		13		—
Rate case amortizations		7		21		7		21
Electric rate case deferral		—		19		—		19
Other		172		162		148		145
Regulatory liabilities		982		858		859		703
Deferred derivative gains – current		3		8		3		8
Total Regulatory Liabilities	$	985	$	866	$	862	$	711

Pension Benefits (Tables)

6 Months Ended

Jun. 30, 2010

Net Periodic Benefit Cost

For the Three Months Ended June 30,
	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Service cost – including administrative expenses	$	42		$	40		$	39		$	37
Interest cost on projected benefit obligation		139			131			130			123
Expected return on plan assets		(176	)		(173	)		(167	)		(165	)
Amortization of net actuarial loss		106			75			100			68
Amortization of prior service costs		2			2			2			2
NET PERIODIC BENEFIT COST	$	113		$	75		$	104		$	65
Amortization of regulatory asset*		1			1			1			1
TOTAL PERIODIC BENEFIT COST	$	114		$	76		$	105		$	66
Cost capitalized		(37	)		(27	)		(34	)		(25	)
Cost deferred		(33	)		(5	)		(32	)		(3	)
Cost charged to operating expenses	$	44		$	44		$	39		$	38

*	Relates to increases in CECONY's pension obligations of $33 million from a 1993 special retirement program and $45 million from a 1999 special retirement program.


	For the Six Months Ended June 30,
	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Service cost – including administrative expenses	$	84		$	80		$	78		$	74
Interest cost on projected benefit obligation		278			262			260			246
Expected return on plan assets		(352	)		(346	)		(334	)		(330	)
Amortization of net actuarial loss		212			150			200			136
Amortization of prior service costs		4			4			4			4
NET PERIODIC BENEFIT COST	$	226		$	150		$	208		$	130
Amortization of regulatory asset*		1			2			1			2
TOTAL PERIODIC BENEFIT COST	$	227		$	152		$	209		$	132
Cost capitalized		(78	)		(54	)		(73	)		(50	)
Cost deferred		(56	)		(36	)		(53	)		(31	)
Cost charged to operating expenses	$	93		$	62		$	83		$	51

*	Relates to increases in CECONY's pension obligations of $33 million from a 1993 special retirement program and $45 million from a 1999 special retirement program.

Other Postretirement Benefits (Tables)

3 Months Ended

6 Months Ended

Jun. 30, 2010

Net Periodic Benefit Cost


	For the Three Months Ended June 30,
	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Service cost	$	6		$	5		$	5		$	4
Interest cost on accumulated other postretirement benefit obligation		23			24			20			21
Expected return on plan assets		(22	)		(21	)		(19	)		(20	)
Amortization of net actuarial loss		23			18			21			16
Amortization of prior service cost		(3	)		(3	)		(4	)		(3	)
Amortization of transition obligation		1			1			1			1
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	28		$	24		$	24		$	19
Cost capitalized		(10	)		(9	)		(8	)		(8	)
Cost deferred		1			—			—			—
Cost charged to operating expenses	$	19		$	15		$	16		$	11


	For the Six Months Ended June 30,
	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Service cost	$	12		$	10		$	10		$	8
Interest cost on accumulated other postretirement benefit obligation		46			48			40			42
Expected return on plan assets		(44	)		(42	)		(38	)		(40	)
Amortization of net actuarial loss		46			36			42			32
Amortization of prior service cost		(6	)		(6	)		(8	)		(6	)
Amortization of transition obligation		2			2			2			2
NET PERIODIC POSTRETIREMENT BENEFIT COST	$	56		$	48		$	48		$	38
Cost capitalized		(20	)		(18	)		(17	)		(15	)
Cost deferred		—			(1	)		(2	)		(2	)
Cost charged to operating expenses	$	36		$	29		$	29		$	21

Environmental Matters (Tables)

3 Months Ended

6 Months Ended

Jun. 30, 2010

Accrued Liabilities and regulatory assets


	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Accrued Liabilities:
Manufactured gas plant sites	$	190	$	164	$	105	$	112
Other Superfund Sites		46		48		46		47
Total	$	236	$	212	$	151	$	159
Regulatory assets	$	417	$	388	$	327	$	329


	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Accrued Liabilities:
Manufactured gas plant sites	$	190	$	164	$	105	$	112
Other Superfund Sites		46		48		46		47
Total	$	236	$	212	$	151	$	159
Regulatory assets	$	417	$	388	$	327	$	329

Environmental remediation costs incurred related to Superfund Sites


	For the Three Months Ended June 30,
	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Remediation costs incurred	$	14	$	24	$	13	$	23


	For the Six Months Ended June 30,
	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Remediation costs incurred	$	23	$	40	$	21	$	39

Accrued liabilities for asbestos suits and workers' compensation proceedings


	Con Edison				CECONY
*(Millions of Dollars)*	2010		2009		2010		2009
Accrued liability – asbestos suits	$	10	$	10	$	9	$	9
Regulatory assets – asbestos suits	$	10	$	10	$	9	$	9
Accrued liability – workers' compensation	$	110	$	113	$	105	$	108
Regulatory assets – workers' compensation	$	35	$	37	$	35	$	37

Other Material Contingencies (Tables)

6 Months Ended

Jun. 30, 2010

Total Guarantees


Guarantee Type	0 – 3 years		4 – 10 years		> 10 years		Total
	*(Millions of Dollars)*
Commodity transactions	$	617	$	9	$	134	$	760
Affordable housing program		4		—		—		4
Intra-company guarantees		30		—		1		31
Other guarantees		65		20		—		85
TOTAL	$	716	$	29	$	135	$	880

Financial Information by Business Segment (Tables)

6 Months Ended

Jun. 30, 2010

Financial data by business segment table


	For the Three Months Ended June 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
*(Millions of Dollars)*	2010			2009			2010			2009			2010		2009		2010			2009
CECONY
Electric	$	2,104		$	1,812		$	2		$	3		$	156	$	146	$	319		$	312
Gas		239			295			1			1			25		24		44			46
Steam		89			113			18			18			15		15		(29	)		(18	)
Consolidation adjustments		—			—			(21	)		(22	)		—		—		—			—
Total CECONY	$	2,432		$	2,220		$	—		$	—		$	196	$	185	$	334		$	340
O&R
Electric	$	153		$	144		$	—		$	—		$	8	$	8	$	15		$	10
Gas		35			39			—			—			3		3		(1	)		—
Total O&R	$	188		$	183		$	—		$	—		$	11	$	11	$	14		$	10
Competitive energy businesses	$	406		$	454		$	—		$	(1	)	$	4	$	1	$	81		$	24
Other*		(9	)		(12	)		—			1			—		—		—			(2	)
Total Con Edison	$	3,017		$	2,845		$	—		$	—		$	211	$	197	$	429		$	372

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


	For the Six Months Ended June 30,
	Operating revenues						Inter-segment revenues						Depreciation and amortization				Operating income
*(Millions of Dollars)*	2010			2009			2010			2009			2010		2009		2010			2009
CECONY
Electric	$	3,832		$	3,469		$	6		$	6		$	307	$	288	$	514		$	458
Gas		922			1,077			2			2			50		49		259			252
Steam		396			444			36			36			31		29		73			65
Consolidation adjustments		—			—			(44	)		(44	)		—		—		—			—
Total CECONY	$	5,150		$	4,990		$	—		$	—		$	388	$	366	$	846		$	775
O&R
Electric	$	314		$	289		$	—		$	—		$	16	$	15	$	22		$	18
Gas		125			145			—			—			6		6		21			20
Total O&R	$	439		$	434		$	—		$	—		$	22	$	21	$	43		$	38
Competitive energy businesses	$	906		$	867		$	—		$	(3	)	$	5	$	2	$	33		$	(18	)
Other*		(17	)		(22	)		—			3			—		—		(1	)		(4	)
Total Con Edison	$	6,478		$	6,269		$	—		$	—		$	415	$	389	$	921		$	791

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

Derivative Instruments and Hedging Activities (Tables)

6 Months Ended

Jun. 30, 2010

Schedule of Energy Price Hedges, Fair Value


	Con Edison						CECONY
*(Millions of Dollars)*	2010			2009			2010			2009
Fair value of net derivative assets/(liabilities) – gross	$	(363	)	$	(266	)	$	(223	)	$	(137	)
Impact of netting of cash collateral		194			162			113			87
Fair value of net derivative assets/(liabilities) – net	$	(169	)	$	(104	)	$	(110	)	$	(50	)

Fair Value of Commodity Derivatives

The fair values of the Companies' commodity derivatives at June 30, 2010 were:


*(Millions of Dollars)*	Fair Value of Commodity Derivatives(a) Balance Sheet Location	Con Edison			CECONY
Asset Derivatives
Current	Fair value of derivative assets	$	199		$	12
Long term	Other deferred charges and non-current assets		128			5
Total asset derivatives		$	327		$	17
Impact of netting			(211	)		8
Net asset derivatives		$	116		$	25
Liability Derivatives
Current	Fair value of derivative liabilities	$	479		$	148
Long term	Fair value of derivative liabilities		211			92
Total liability derivatives		$	690		$	240
Impact of netting			(405	)		(105	)
Net liability derivatives		$	285		$	135

(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 value of the Companies' commodity derivatives at December 31, 2009 were:


*(Millions of Dollars)*	Fair Value of Commodity Derivatives(a) Balance Sheet Location	Con Edison			CECONY
Asset Derivatives
Current	Fair value of derivative assets	$	213		$	40
Long term	Other deferred charges and non-current assets		148			19
Total asset derivatives		$	361		$	59
Impact of netting			(231	)		(20	)
Net asset derivatives		$	130		$	39
Liability Derivatives
Current	Fair value of derivative liabilities	$	401		$	110
Long term	Fair value of derivative liabilities		226			86
Total liability derivatives		$	627		$	196
Impact of netting			(393	)		(107	)
Net liability derivatives		$	234		$	89

(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.

Change in Fair Value of Commodity Derivatives Deferred or Recognized in Earnings


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Three Months Ended June 30, 2010
*(Millions of Dollars)*	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	1		$	1
Total deferred gains		$	1		$	1
Current	Deferred derivative losses	$	95		$	78
Current	Recoverable energy costs	$	(80	)	$	(67	)
Long term	Regulatory assets	$	51		$	38
Total deferred losses		$	66		$	49
Net deferred losses		$	67		$	50
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(43	)(b)	$	—
	Gas purchased for resale		(11	)		—
	Non-utility revenue		2	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(52	)	$	—

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

(b)	For the three months ended June 30, 2010, Con Edison recorded in non-utility operating revenues and purchased power expense an unrealized pre-tax gain/(loss) of $(45) million and $110 million, respectively.


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the six Months Ended June 30, 2010
*(Millions of Dollars)*	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$	(5	)	$	(5	)
Total deferred gains		$	(5	)	$	(5	)
Current	Deferred derivative losses	$	(66	)	$	(60	)
Current	Recoverable energy costs	$	(135	)	$	(109	)
Long term	Regulatory assets	$	(23	)	$	(18	)
Total deferred losses		$	(224	)	$	(187	)
Net deferred losses		$	(229	)	$	(192	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(106	)(b)	$	—
	Gas purchased for resale		(6	)		—
	Non-utility revenue		17	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(95	)	$	—

(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 six months ended June 30, 2010, Con Edison recorded in non-utility operating revenues an unrealized pre-tax gain/(loss) of $2 million.

The following table presents the changes in the fair values of commodity derivatives that have been deferred or recognized in earnings for the three and six months ended June 30, 2009:


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Three Months Ended June 30, 2009
*(Millions of Dollars)*	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with FAS71:
Current	Deferred derivative gains	$	(9	)	$	(9	)
Total deferred gains		$	(9	)	$	(9	)
Current	Deferred derivative losses	$	65		$	66
Current	Recoverable energy costs	$	(122	)	$	(102	)
Long term	Regulatory assets	$	25		$	15
Total deferred losses		$	(32	)	$	(21	)
Net deferred losses		$	(41	)	$	(30	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(144	)	$	—
	Gas purchased for resale		(1	)		—
	Non-utility revenue		139	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(6	)	$	—

(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 hedgingand, therefore, are excluded from the table.

(b)	For the three months ended June 30, 2009, Con Edison recorded in non-utility operating revenues an unrealized pre-tax gain of $31 million.


Realized and Unrealized Gains/(Losses) on Commodity Derivatives(a) Deferred or Recognized in Income for the Six Months Ended June 30, 2009
*(Millions of Dollars)*	Balance Sheet Location	Con Edison			CECONY
Pre-tax gains/(losses) deferred in accordance with FAS71:
Current	Deferred derivative gains	$	(13	)	$	(13	)
Total deferred gains		$	(13	)	$	(13	)
Current	Deferred derivative losses	$	25		$	40
Current	Recoverable energy costs	$	(303	)	$	(259	)
Long term	Regulatory assets	$	(20	)	$	(16	)
Total deferred losses		$	(298	)	$	(235	)
Net deferred losses		$	(311	)	$	(248	)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$	(255	)	$	—
	Gas purchased for resale		2			—
	Non-utility revenue		215	(b)		—
Total pre-tax gain/(loss) recognized in income		$	(38	)	$	—

(c)	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.

(d)	For the six months ended June 30, 2009, Con Edison recorded in non-utility operating revenues an unrealized pre-tax loss of $26 million.

Number of Derivative Contracts by Commodity Type

Electric Derivatives				Gas Derivatives
	Number of Energy Contracts(a)	MWhs(b)	Number of Capacity Contracts(a)	MWs(b)	Number of Contracts(a)	Dths(b)	Total Number Of Contracts(a)
Con Edison	692	17,552,057	45	8,013	685	112,842,500	1,422
CECONY	123	3,703,750	—	—	554	105,250,000	677

(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	$	374		$	149
Collateral posted	$	212		$	73	(b)
Additional collateral(c) (downgrade one level from current ratings(d))	$	33		$	27
Additional collateral(c) (downgrade to below investment grade from current ratings(d))	$	301	(e)	$	89

(a)

(b)	Across the Utilities' energy derivative positions, credit limits for the same counterparties are generally integrated. At June 30, 2010, the Utilities posted combined collateral of $117 million, including an estimated $44 million attributable to O&R.

(c)

(d)

(e)	Derivative instruments that are net assets have been excluded from the table. At June 30, 2010, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of not more than $20 million.

- Definition

This element may be used to tag a single block of text that encapsulates the entire credit derivatives disclosure including data and tables. This disclosures provides pertinent 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, a credit-linked note).

+ References+ Details

Fair Value Measurements (Tables)

6 Months Ended

12 Months Ended

Jun. 30, 2010

Dec. 31, 2009

Assets and Liabilities Measured at Fair Values on a Recurring Basis

Level 1

Level 2

Level 3

Netting

Adjustments(4)

Total

(Millions of Dollars)

Con
Edison

CECONY

Con
Edison

CECONY

Con
Edison

CECONY

Con
Edison

CECONY

Con
Edison

CECONY

Derivative assets:
Commodity	$	—	$	—	$	69		$	7		$	195		$	5		$	(148	)	$	13		$	116		$	25
Transfers in(5)(6)		—		—		—			—			2			2			—			—			2			2
Transfers out(5)(6)		—		—		(2	)		(2	)		—			—			—			—			(2	)		(2	)
Commodity(1)		—		—		67			5			197			7			(148	)		13			116			25
Other assets(3)		58		58		—			—			94			85			—			—			152			143
Total	$	58	$	58	$	67		$	5		$	291		$	92		$	(148	)	$	13		$	268		$	168
Derivative liabilities:
Commodity	$	6	$	5	$	303		$	173		$	318		$	57		$	(342	)	$	(100	)	$	285		$	135
Transfers in(5)(7)		—		—		20			20			—			—			—			—			20			20
Transfers out(5)(7)		—		—		—			—			(20	)		(20	)		—			—			(20	)		(20	)
Commodity(1)		6		5		323			193			298			37			(342	)		(100	)		285			135
Interest rate contract(2)		—		—		—			—			12			—			—			—			12			—
Total	$	6	$	5	$	323		$	193		$	310		$	37		$	(342	)	$	(100	)	$	297		$	135

(1)

(2)	See Note J.

(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 March 31, 2010 to less than one year as of June 30, 2010.

Assets and liabilities measured at fair value on a recurring basis as of December 31, 2009 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	$	3	$	92	$	21	$	201	$	17	$	(166	)	$	(2	)	$	130	$	39
Other assets(3)		36		36		—		—		92		83		—			—			128		119
Total	$	39	$	39	$	92	$	21	$	293	$	100	$	(166	)	$	(2	)	$	258	$	158
Derivative liabilities:
Commodity(1)	$	6	$	1	$	296	$	155	$	260	$	22	$	(328	)	$	(89	)	$	234	$	89
Interest rate contract(2)		—		—		—		—		11		—		—			—			11		—
Total	$	6	$	1	$	296	$	155	$	271	$	22	$	(328	)	$	(89	)	$	245	$	89

(1)

(2)	See Note O to the financial statements in Item 8 of the Form 10-K.

(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.

Table of Reconciliations for Assets and Liabilities Measured at Fair Value on a Recurring Basis Using Significant Unobservable Inputs (Level 3)

For the Three Months Ended June 30, 2010
			Total Gains/(Losses) – Realized and Unrealized
*(Millions of Dollars)*	Beginning Balance as of April 1, 2010		Included in Earnings		Included in Regulatory Assets and Liabilities		Purchases, Issuances, Sales and Settlements		Transfer In/Out of Level 3	Ending Balance as of June 30, 2010
Con Edison
Derivatives:
Commodity	(168	)	1		34		14		18	(101	)
Interest rate contract	(11	)	(1	)	(1	)	1		—	(12	)
Other(1)	93		—		1		—		—	94
Total	(86	)	—		34		15		18	(19	)
CECONY
Derivatives:
Commodity	(48	)	(2	)	4		(2	)	18	(30	)
Other(1)	84		—		1		—		—	85
Total	36		(2	)	5		(2	)	18	55

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


	For the Six Months Ended June 30, 2010
			Total Gains/(Losses) – Realized and Unrealized
*(Millions of Dollars)*	Beginning Balance as of January 1, 2010		Included in Earnings		Included in Regulatory Assets and Liabilities		Purchases, Issuances, Sales and Settlements		Transfer In/Out of Level 3	Ending Balance as of June 30, 2010
Con Edison
Derivatives:
Commodity	(59	)	(50	)	(38	)	28		18	(101	)
Interest rate contract	(11	)	(2	)	(1	)	2		—	(12	)
Other(1)	92		—		2		—		—	94
Total	22		(52	)	(37	)	30		18	(19	)
CECONY
Derivatives:
Commodity	(5	)	(7	)	(29	)	(7	)	18	(30	)
Other(1)	83		—		2		—		—	85
Total	78		(7	)	(27	)	(7	)	18	55

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

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value for the three and six months ended June 30, 2009 and classified as Level 3 in the fair value hierarchy:


	For the Three Months Ended June 30, 2009
				Total Gains/(Losses) – Realized and Unrealized
*(Millions of Dollars)*	Beginning Balance as of April 1, 2009			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases, Issuances, Sales and Settlements		Transfer In/Out of Level 3		Ending Balance as of June 30, 2009
Con Edison
Derivatives:
Energy	$	(115	)	$	(76	)	$	1		$	105	$	—	$	(85	)
Financial & other		(14	)		—			2			—		—		(12	)
Other		68			5			9			—		—		82
Total	$	(61	)	$	(71	)	$	12		$	105	$	—	$	(15	)
CECONY
Derivatives:
Energy	$	(7	)	$	(5	)	$	(7	)	$	21	$	—	$	2
Other		61			5			8			—		—		74
Total	$	54		$	—		$	1		$	21	$	—	$	76


	For the Six Months Ended June 30, 2009
				Total Gains/(Losses) – Realized and Unrealized
*(Millions of Dollars)*	Beginning Balance as of January 1, 2009			Included in Earnings			Included in Regulatory Assets and Liabilities			Purchases, Issuances, Sales and Settlements		Transfer In/Out of Level 3		Ending Balance as of June 30, 2009
Con Edison
Derivatives:
Energy	$	(50	)	$	(105	)	$	(51	)	$	121	$	—	$	(85	)
Financial & other		(15	)		—			3			—		—		(12	)
Other		73			3			6			—		—		82
Total	$	8		$	(102	)	$	(42	)	$	121	$	—	$	(15	)
CECONY
Derivatives:
Energy	$	1		$	(6	)	$	(15	)	$	22	$	—	$	2
Other		65			3			6			—		—		74
Total	$	66		$	(3	)	$	(9	)	$	22	$	—	$	76

Summary of Significant Accounting Policies (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended				6 Months Ended
	Jun. 30, 2010	Mar. 31, 2010	Jun. 30, 2009	Mar. 31, 2009	Jun. 30, 2010	Jun. 30, 2009
Net income for common stock	$ 183	$ 226	$ 150	$ 180	$ 409	$ 330
Weighted average common shares outstanding - Basic	282.0		274.5		281.7	274.2
Add: Incremental shares attributable to effect of potentially dilutive securities	1.5		0.8		1.5	0.8
Adjusted weighted average common shares outstanding - Diluted	283.5		275.3		283.2	275.0
Net income for common stock per common share - basic	$ 0.65		$ 0.55		$ 1.45	$ 1.2
Net income for common stock per common share - diluted	$ 0.64		$ 0.55		$ 1.44	$ 1.2

Regulatory Matters (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2010	May 17, 2010	Dec. 31, 2009	Jul. 31, 2011 O&R [Member]	Jun. 30, 2010 Unrecognized Pension And Other Postretirement Costs [Member]	Dec. 31, 2009 Unrecognized Pension And Other Postretirement Costs [Member]	Jun. 30, 2010 Future federal income tax [Member]	Dec. 31, 2009 Future federal income tax [Member]	Jun. 30, 2010 Environmental Remediation Costs [Member]	Dec. 31, 2009 Environmental Remediation Costs [Member]	Jun. 30, 2010 Net Electric Deferrals [Member]	Dec. 31, 2009 Net Electric Deferrals [Member]	Jun. 30, 2010 Surcharge for New York State Assessment [Member]	Dec. 31, 2009 Surcharge for New York State Assessment [Member]	Jun. 30, 2010 Deferred derivative losses-long-term [Member]	Dec. 31, 2009 Deferred derivative losses-long-term [Member]	Jun. 30, 2010 Revenue Taxes [Member]	Dec. 31, 2009 Revenue Taxes [Member]	Jun. 30, 2010 Pension And Other Post Retirement Benefits Deferrals [Member]	Dec. 31, 2009 Pension And Other Post Retirement Benefits Deferrals [Member]	Jun. 30, 2010 Property Tax Reconciliation [Member]	Dec. 31, 2009 Property Tax Reconciliation [Member]	Jun. 30, 2010 O and R Transition Bond Charges [Member]	Dec. 31, 2009 O and R Transition Bond Charges [Member]	Jun. 30, 2010 World Trade Center Restoration Costs [Member]	Dec. 31, 2009 World Trade Center Restoration Costs [Member]	Jun. 30, 2010 Workers Compensations [Member]	Dec. 31, 2009 Workers Compensations [Member]	Jun. 30, 2010 Storm Reserves [Member]	Dec. 31, 2009 Storm Reserves [Member]	Jun. 30, 2010 Other [Member]	Dec. 31, 2009 Other [Member]	Jun. 30, 2010 Deferred derivative losses-current [Member]	Dec. 31, 2009 Deferred derivative losses-current [Member]	Jun. 30, 2010 Recoverable energy costs-current [Member]	Dec. 31, 2009 Recoverable energy costs-current [Member]	Jun. 30, 2010 Allowance for cost of removal less salvage [Member]	Dec. 31, 2009 Allowance for cost of removal less salvage [Member]	Jun. 30, 2010 Refundable Energy Costs [Member]	Dec. 31, 2009 Refundable Energy Costs [Member]	Jun. 30, 2010 Net unbilled revenue deferrals [Member]	Dec. 31, 2009 Net unbilled revenue deferrals [Member]	Jun. 30, 2010 Revenue Decoupling Mechanism over collection [Member]	Jun. 30, 2010 New York State Tax Refund [Member]	Jun. 30, 2010 2005-2008 capital expenditure reserve [Member]	Dec. 31, 2009 2005-2008 capital expenditure reserve [Member]	Jun. 30, 2010 Gain On Sale Of First Avenue Properties [Member]	Dec. 31, 2009 Gain On Sale Of First Avenue Properties [Member]	Jun. 30, 2010 Gain on sale of 125th Street Property [Member]	Jun. 30, 2010 Rate Case Amortization [Member]	Dec. 31, 2009 Rate Case Amortization [Member]	Dec. 31, 2009 Electric Rate Case Deferral [Member]	Jun. 30, 2010 Other Liabilities [Member]	Dec. 31, 2009 Other Liabilities [Member]	Jun. 30, 2010 Deferred Derivative Gains Current [Member]	Dec. 31, 2009 Deferred Derivative Gains Current [Member]	Jul. 31, 2013 Alternative proposal [Member]	Jul. 31, 2012 Alternative proposal [Member]	Jul. 31, 2011 Alternative proposal [Member]
Electric rate increase		$ 9.80		$ 61.70																																																						$ 33.20	$ 47.10
Return on common equity		10.30%		11.00%																																																					11.55%
Common equity ratio		50.00%		49.90%
Regulatory assets	7,026		7,103		4,128	4,472	1,390	1,316	417	388	177	82	156	138	129	106	129	119	135	101	43	85	50	55	36	41	35	37	49	5
Total Regulatory Assets	229		201
Regulatory Assets, Current	7,255		7,304																														207	141	22	60
Regulatory liabilities	982		858																												152	158					394	371	136	147	146	91	37	28	26	24	23	23	13	7	21	19	172	162
Total Regulatory Liabilities	985		866
Regulatory Liability, Current																																																							$ 3	$ 8

Short-Term Borrowing (Details) (USD $) In Millions, unless otherwise specified	Jun. 30, 2010	Dec. 31, 2009
Commercial Paper Outstanding	$ 153
Weighted Average Interest Rate	0.40%
Letters of Credit Outstanding Under the Credit Agreement	248	193
CECONY [Member]
Commercial Paper Outstanding	66
Letters of Credit Outstanding Under the Credit Agreement	$ 162	$ 135

Pension Benefits (Details) (USD $) In Millions, unless otherwise specified	12 Months Ended	3 Months Ended		6 Months Ended			12 Months Ended	3 Months Ended
	Dec. 31, 2010 CONSOLIDATED EDISON INC [Member]	Jun. 30, 2010 Defined Benefit Pension [Member]	Jun. 30, 2009 Defined Benefit Pension [Member]	Jun. 30, 2010 Defined Benefit Pension [Member]	Jun. 30, 2009 Defined Benefit Pension [Member]	Jun. 30, 2010 Defined Benefit Pension [Member] CECONY [Member]	Dec. 31, 2010 Defined Benefit Pension [Member] CECONY [Member]	Jun. 30, 2010 Other Nonqualified Supplemental Defined Benefit Pension [Member]
Service cost - including administrative expenses		$ 42	$ 40	$ 84	$ 80
Interest cost on projected benefit obligation		139	131	278	262
Expected return on plan assets		(176)	(173)	(352)	(346)
Amortization of net actuarial loss		106	75	212	150
Amortization of prior service costs		2	2	4	4
Net Periodic Benefit Cost		113	75	226	150
Amortization of regulatory asset*		1	1	1	2
Total Periodic Benefit Cost		114	76	227	152
Cost capitalized		(37)	(27)	(78)	(54)
Cost deferred		(33)	(5)	(56)	(36)
Cost charged to operating expenses		44	44	93	62
Expected discretionary contributions to pension plan	$ 434					$ 279	$ 397	$ 25

Other Postretirement Benefits (Details) (Other Postretirement Benefit Plans, Defined Benefit [Member], USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2010	Jun. 30, 2009	Jun. 30, 2010	Jun. 30, 2009
Other Postretirement Benefit Plans, Defined Benefit [Member]
Service cost	$ 6	$ 5	$ 12	$ 10
Interest cost on accumulated other postretirement benefit obligation	23	24	46	48
Expected return on plan assets	(22)	(21)	(44)	(42)
Amortization of net actuarial loss	23	18	46	36
Amortization of prior service costs	(3)	(3)	(6)	(6)
Amortization of transition obligation	1	1	2	2
Net Periodic Postretirement Benefit Cost	28	24	56	48
Cost capitalized	(10)	(9)	(20)	(18)
Cost deferred	1			(1)
Cost charged to operating expenses	$ 19	$ 15	$ 36	$ 29

Environmental Matters (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2010	Jun. 30, 2009	Jun. 30, 2010	Jun. 30, 2009	Dec. 31, 2009
Regulatory assets	$ 229		$ 229		$ 201
Remediation costs incurred	14	24	23	40
Undiscounted potential liability for the investigation of manufactured gas plant-related contaminants, O&R	115		115
Accrued liability - asbestos suits	10		10		10
Regulatory assets - asbestos suits	10		10		10
Accrued liability - workers compensation	110		110		113
Regulatory assets - workers compensation	35		35		37
Superfund Sites [Member]
Manufactured gas plant sites	190		190		164
Other Superfund Sites	46		46		48
Total	236		236		212
Regulatory assets	$ 417		$ 417		$ 388

Other Material Contingencies (Details) (USD $) In Millions, unless otherwise specified							6 Months Ended
	Jun. 30, 2010	Dec. 31, 2009	Jun. 30, 2010 Financial And Performance Guarantee For Commodity Transactions [Member]	Jun. 30, 2010 Financial And Performance Guarantee For Affordable Housing Program [Member]	Jun. 30, 2010 Financial And Performance Guarantee For Intra Company [Member]	Jun. 30, 2010 Financial And Performance Guarantee Other [Member]	Jun. 30, 2010 Tax deficiency paid in December 2005 [Member]	Jun. 30, 2010 Interest in April 2006 [Member]	Jun. 30, 2010 Interest up to June 2010 [Member]	Jun. 30, 2010 Disallowance of Tax 2008 [Member]	Jun. 30, 2010 Guarantee duration, 0-3 years [Member]	Jun. 30, 2010 Guarantee duration, 0-3 years [Member] Financial And Performance Guarantee For Commodity Transactions [Member]	Jun. 30, 2010 Guarantee duration, 0-3 years [Member] Financial And Performance Guarantee For Affordable Housing Program [Member]	Jun. 30, 2010 Guarantee duration, 0-3 years [Member] Financial And Performance Guarantee For Intra Company [Member]	Jun. 30, 2010 Guarantee duration, 0-3 years [Member] Financial And Performance Guarantee Other [Member]	Jun. 30, 2010 Guarantee duration, 4-10 years [Member]	Jun. 30, 2010 Guarantee duration, 4-10 years [Member] Financial And Performance Guarantee For Commodity Transactions [Member]	Jun. 30, 2010 Guarantee duration, 4-10 years [Member] Financial And Performance Guarantee Other [Member]	Jun. 30, 2010 Guarantee duration, greater than 10 years [Member]	Jun. 30, 2010 Guarantee duration, greater than 10 years [Member] Financial And Performance Guarantee For Commodity Transactions [Member]	Jun. 30, 2010 Guarantee duration, greater than 10 years [Member] Financial And Performance Guarantee For Intra Company [Member]
Guarantee Obligations Maximum Exposure	$ 880	$ 929	$ 760	$ 4	$ 31	$ 85					$ 716	$ 617	$ 4	$ 30	$ 65	$ 29	$ 9	$ 20	$ 135	$ 134	$ 1
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	(33)	(24)
Gross investment in leverage leases	235	235
Deferred tax liabilities	268	259
Tax deficiency paid to IRS							0.3
Interest paid related to tax deficiency								0.2	71.0
Disallowed deduction	416									42
Tax savings From LILO transactions	$ 213

Financial Information by Business Segment (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2010	Jun. 30, 2009	Jun. 30, 2010	Jun. 30, 2009
O&R [Member]
Operating revenues	$ 188	$ 183	$ 439	$ 434
Depreciation and amortization	11	11	22	21
Operating income	14	10	43	38
CECONY [Member]
Operating revenues	2,432	2,220	5,150	4,990
Depreciation and amortization	196	185	388	366
Operating income	334	340	846	775
Consolidation Adjustments [Member]
Inter-segment revenues	(21)	(22)	(44)	(44)
CONSOLIDATED EDISON INC [Member]
Operating revenues	3,017	2,845	6,478	6,269
Depreciation and amortization	211	197	415	389
Operating income	429	372	921	791
CECONY - Electric [Member]
Operating revenues	2,104	1,812	3,832	3,469
Inter-segment revenues	2	3	6	6
Depreciation and amortization	156	146	307	288
Operating income	319	312	514	458
CECONY - Gas [Member]
Operating revenues	239	295	922	1,077
Inter-segment revenues	1	1	2	2
Depreciation and amortization	25	24	50	49
Operating income	44	46	259	252
CECONY - Steam [Member]
Operating revenues	89	113	396	444
Inter-segment revenues	18	18	36	36
Depreciation and amortization	15	15	31	29
Operating income	(29)	(18)	73	65
O&R - Electric [Member]
Operating revenues	153	144	314	289
Depreciation and amortization	8	8	16	15
Operating income	15	10	22	18
O&R - Gas [Member]
Operating revenues	35	39	125	145
Depreciation and amortization	3	3	6	6
Operating income	(1)		21	20
Competitive Energy Businesses [Member]
Operating revenues	406	454	906	867
Inter-segment revenues		(1)		(3)
Depreciation and amortization	4	1	5	2
Operating income	81	24	33	(18)
Other Revenues and Eliminations in Segment Information [Member]
Operating revenues	(9)	(12)	(17)	(22)
Inter-segment revenues		1		3
Operating income		$ (2)	$ (1)	$ (4)

Derivative Instruments and Hedging Activities (Details) (USD $)
In Millions, unless otherwise specified

3 Months Ended

6 Months Ended

Jun. 30, 2010

Jun. 30, 2009

Jun. 30, 2010

Jun. 30, 2009

Dec. 31, 2009

Fair value of net derivative assets/(liabilities) Gross

$ (363)

$ (266)

Impact of netting of cash collateral

194

162

Fair value of net derivative assets/(liabilities) net

(169)

(104)

Con Edison and CECONY energy supply and hedging activities credit exposure Total

173

ConEdison makeup of net credit exposure counterparties

116

ConEdison makeup of net credit exposure counterparties

Net Asset Derivatives

116

130

Net Liability Derivatives

285

234

Current-Deferred derivative gains

(9)

^[1]

(13)

^[1]

Deferred Derivative Gains Total

(9)

(5)

(13)

Deferred Derivative Losses Current

(66)

Deferred Derivative Current Recoverable Energy Costs

(80)

(122)

(135)

(303)

Deferred Derivative Long Term Regulatory Assets

(23)

(20)

Deferred Derivative Losses Total

(32)

(224)

(298)

Net Deferred Derivative Losses

(41)

(229)

(311)

Derivative Instruments Gain Loss Recognized In Income Net

(52)

(6)

(95)

(38)

Aggregate Fair Value - net liabilities

374

^[2]

374

^[2]

Collateral Posted

212

^[2]

212

^[2]

Number of Energy Contracts

1,422

Fair Value loss of Interest Rate Swap recorded as noncurrent liability

Purchased power expense [Member]

Derivative Instruments Gain Loss Recognized In Income Net

(43)

(144)

(106)

(255)

Derivative Instruments Gain Loss Recognized In Income Net Gas Purchased For Resale [Member]

Derivative Instruments Gain Loss Recognized In Income Net

(11)

(1)

(6)

Non-utility operating revenues [Member]

Derivative Instruments Gain Loss Recognized In Income Net

139

^[3]

215

^[4]

Derivatives Not Designated As Hedging Instruments Economic Hedges Current Asset [Member]

Current Fair Value of Derivative Assets

199

^[1]

199

^[1]

213

^[1]

Derivatives Not Designated As Hedging Instruments Economic Hedges Long Term Asset [Member]

Current Fair Value of Derivative Assets

128

148

Derivative Fair Value Of Derivative Asset Amount Offset Against Collateral Commodity Derivative [Member]

Current Fair Value of Derivative Assets

327

361

Impact of netting

(211)

(231)

Derivatives Not Designated As Hedging Instruments Economic Hedges Current Liability [Member]

Current Fair Value of Derivative Liabilities

479

401

Derivatives Not Designated As Hedging Instruments Economic Hedges Long Term Liability [Member]

Current Fair Value of Derivative Liabilities

226

Derivative Fair Value Of Derivative Liability Amount Offset Against Collateral Commodity Derivative [Member]

Current Fair Value of Derivative Assets

211

Impact of netting

(405)

(393)

Current Fair Value of Derivative Liabilities

690

627

Description Of Derivative Activity Volume Electric Derivatives [Member]

Number of Energy Contracts

692

^[1]

Mwhs

17,552,057

^[5]

Number of Capacity Contracts

^[1]

MWs

8,013

^[5]

Description Of Derivative Activity Volume Gas Derivatives [Member]

Number of Energy Contracts

685

^[1]

Dths

112,842,500

^[5]

Number of Contracts considered to be considered derivatives

1,422

^[1]

Additional Collateral Aggregate Fair Value Down One Level [Member]

Additional Collateral downgrade one level

^[2],[6],[7]

Additional Collateral Aggregate Fair Value Down Below Investment Grade [Member]

Additional Collateral downgrade one level

$ 301

^{[2],[6],[7],[8]}

$ 301

^{[2],[6],[7],[8]}

[1]	Qualifying derivative contracts, which have been designated as normal purchases or normal sales contracts, are not reported at fair value under the accounting rules for derivatives and hedging and, therefore, are excluded from the table.
[2]	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 June 30, 2010, would have amounted to an estimated $194 million for Con Edison, including $121 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.
[3]	For the six months ended June 30, 2010, Con Edison recorded in non-utility operating revenues an unrealized pre-tax gain/(loss) of $2 million.
[4]	For the six months ended June 30, 2009, Con Edison recorded in non-utility operating revenues an unrealized pre-tax loss of $26 million.
[5]	Volumes are reported net of long and short positions.
[6]	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.
[7]	The current ratings are Moody's, S&P and Fitch long-term credit rating of, as applicable, Con Edison (Baa1/BBB+/BBB+), CECONY (A3/A-/A-) or O&R (Baa1/A-/A). Credit ratings assigned by rating agencies are expressions of opinions that are subject to revision or withdrawal at any time by the assigning rating agency.
[8]	Derivative instruments that are net assets have been excluded from the table. At June 30, 2010, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of not more than $20 million.

Derivative Instruments and Hedging Activities (Parenthetical) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2010	Jun. 30, 2009	Jun. 30, 2010	Jun. 30, 2009
Collateral Required If Additional Unsecured Credit Not Available	$ 194
Additional Collateral Con Edison Downgraded Below Investment Grade	20		20
Non-utility operating revenues [Member]
Derivative Instruments Gain Loss Recognized In Income Net Non Utility Revenue	45	31	2	26
Purchased power expense [Member]
Derivative Instruments Gain Loss Recognized In Income Net Non Utility Revenue	$ 110

Fair Value Measurements (Details) (USD $)
In Millions, unless otherwise specified

12 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

Dec. 31, 2009

Jun. 30, 2010

Dec. 31, 2009

Fair Value, Inputs, Level 1 [Member]

Jun. 30, 2010

Fair Value, Inputs, Level 1 [Member]

Dec. 31, 2009

Fair Value, Inputs, Level 2 [Member]

Jun. 30, 2010

Fair Value, Inputs, Level 2 [Member]

Dec. 31, 2009

Fair Value, Inputs, Level 3 [Member]

Jun. 30, 2010

Fair Value, Inputs, Level 3 [Member]

Dec. 31, 2009

Fair Value, Concentration of Credit Risk, Master Netting Arrangements [Member]

Jun. 30, 2010

Fair Value, Concentration of Credit Risk, Master Netting Arrangements [Member]

Jun. 30, 2010

Fair Value Commodity [Member]

Jun. 30, 2010

Fair Value Commodity [Member]

Jun. 30, 2010

Fair Value Commodity [Member]

Fair Value, Inputs, Level 1 [Member]

Jun. 30, 2010

Fair Value Commodity [Member]

Fair Value, Inputs, Level 2 [Member]

Jun. 30, 2010

Fair Value Commodity [Member]

Fair Value, Inputs, Level 3 [Member]

Jun. 30, 2010

Fair Value Commodity [Member]

Fair Value, Concentration of Credit Risk, Master Netting Arrangements [Member]

Jun. 30, 2010

Fair Value Interest Rate Contract [Member]

Jun. 30, 2010

Fair Value Interest Rate Contract [Member]

Dec. 31, 2009

Fair Value Interest Rate Contract [Member]

Dec. 31, 2009

Fair Value Interest Rate Contract [Member]

Fair Value, Inputs, Level 3 [Member]

Jun. 30, 2010

Fair Value Other Derivative [Member]

Dec. 31, 2009

Fair Value Other Derivative [Member]

Jun. 30, 2010

Fair Value Other Derivative [Member]

Fair Value, Inputs, Level 1 [Member]

Dec. 31, 2009

Fair Value Other Derivative [Member]

Fair Value, Inputs, Level 1 [Member]

Jun. 30, 2010

Fair Value Other Derivative [Member]

Fair Value, Inputs, Level 3 [Member]

Dec. 31, 2009

Fair Value Other Derivative [Member]

Fair Value, Inputs, Level 3 [Member]

Jun. 30, 2009

Energy [Member]

Jun. 30, 2009

Energy [Member]

Jun. 30, 2008

Energy [Member]

Jun. 30, 2009

Financial & other [Member]

Jun. 30, 2009

Financial & other [Member]

Jun. 30, 2008

Financial & other [Member]

Jun. 30, 2010

Fair Value Other [Member]

Jun. 30, 2009

Fair Value Other [Member]

Jun. 30, 2010

Fair Value Other [Member]

Jun. 30, 2009

Fair Value Other [Member]

Jun. 30, 2008

Fair Value Other [Member]

Jun. 30, 2010

Fair Value Total [Member]

Jun. 30, 2009

Fair Value Total [Member]

Jun. 30, 2010

Fair Value Total [Member]

Jun. 30, 2009

Fair Value Total [Member]

Jun. 30, 2008

Fair Value Total [Member]

Jun. 30, 2010

Fair Value Gain Loss Include In Non Utility Revenue [Member]

Jun. 30, 2009

Fair Value Gain Loss Include In Non Utility Revenue [Member]

Jun. 30, 2010

Fair Value Gain Loss Include In Non Utility Revenue [Member]

Jun. 30, 2009

Fair Value Gain Loss Include In Non Utility Revenue [Member]

Jun. 30, 2010

Fair Value Gain Loss Include In Purchased Power Costs [Member]

Jun. 30, 2009

Fair Value Gain Loss Include In Purchased Power Costs [Member]

Jun. 30, 2010

Fair Value Gain Loss Include In Purchased Power Costs [Member]

Jun. 30, 2009

Fair Value Gain Loss Include In Purchased Power Costs [Member]

Jun. 30, 2010

Fair Value Change Include In Non Utility Revenue [Member]

Jun. 30, 2009

Fair Value Change Include In Non Utility Revenue [Member]

Jun. 30, 2010

Fair Value Change Include In Non Utility Revenue [Member]

Jun. 30, 2009

Fair Value Change Include In Non Utility Revenue [Member]

Jun. 30, 2009

Fair Value Change Include In Purchased Power Costs [Member]

Jun. 30, 2010

Fair Value Change Include In Purchased Power Costs [Member]

Derivative Assets

$ 130

$ 268

$ 3

$ 58

$ 92

$ 67

$ 201

$ 291

$ (166)

$ (148)

$ 116

$ 69

$ 195

$ (148)

$ 152

$ 128

$ 58

$ 36

$ 94

$ 92

Derivative Assets Commodity Total

258

293

(166)

116

^[1]

116

^[1]

197

^[1]

(148)

^[1]

Fair Value Of Commodity Derivative Assets Transfers In

Fair Value of Commodity Derivative Assets Transfers Out

(2)

Derivative Liabilities

234

297

296

323

260

310

(328)

(342)

285

303

318

(342)

Derivative Liabilities Commodity Total

245

296

271

(328)

285

^[1]

323

^[1]

298

^[1]

(342)

^[1]

Fair Value Of Commodity Derivative Liabilities Transfers In

Fair Value of Commodity Derivative Liabilities Transfers Out

(20)

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value, Beginning Balance

(168)

(59)

(11)

(115)

(50)

(85)

(14)

(15)

(12)

^[2]

(86)

(61)

(15)

Included in Earnings

(50)

(1)

(2)

(76)

(105)

(71)

(52)

(102)

Included in regulatory Assets and Liabilities

(38)

(1)

(51)

^[2]

(37)

(42)

Purchases, Issuances, Sales and settlements

105

121

105

121

Transfers in/Out of Level 3

Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value, Ending Balance

(101)

(12)

(85)

(12)

^[2]

(19)

(15)

(19)

(15)

Competitive energy Business Realized and unrealized gains and losses on level 3 commodity derivative assets and liabilities included in non-utility revenues

Change in Unrealized Gain (Loss) on Fair Value Hedging Instruments

$ 45

$ 11

$ 1

$ 64

$ 7

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

Pension Benefits (Parenthetical) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended	6 Months Ended
	Jun. 30, 2010	Jun. 30, 2010
Special retirement program from 1993 [Member]
Increase in Pension Plan Obligations		$ 33
Special retirement program from 1999 [Member]
Increase in Pension Plan Obligations	$ 45	$ 45