Consolidated Edison (ED) 10-Q 2 May 19 2019 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	Apr. 30, 2019
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	ED
Entity Registrant Name	CONSOLIDATED EDISON INC
Entity Central Index Key	0001047862
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		327,053,801
CECONY
Document Information [Line Items]
Entity Registrant Name	CONSOLIDATED EDISON CO OF NEW YORK INC
Entity Central Index Key	0000023632
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false

Consolidated Income Statement (

Consolidated Income Statement (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
OPERATING REVENUES
Total operating revenues	$ 3,514	$ 3,364
OPERATING EXPENSES
Depreciation and amortization	413	348
Taxes, other than income taxes	605	570
TOTAL OPERATING EXPENSES	2,728	2,609
OPERATING INCOME	786	755
OTHER INCOME (DEDUCTIONS)
Investment income	24	20
Other income	11	6
Allowance for equity funds used during construction	3	4
Other deductions	(24)	(45)
TOTAL OTHER INCOME (DEDUCTIONS)	14	(15)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	800	740
INTEREST EXPENSE
Interest on long-term debt	221	190
Other interest	29	7
Allowance for borrowed funds used during construction	(3)	(2)
NET INTEREST EXPENSE	247	195
INCOME BEFORE INCOME TAX EXPENSE	553	545
INCOME TAX EXPENSE	108	117
NET INCOME	445	428
Income attributable to non-controlling interest	21	0
Net income for common stock	$ 424	$ 428
Net income per common share - basic (dollars per share)	$ 1.31	$ 1.38
Net income per common share - diluted (dollars per share)	$ 1.31	$ 1.37
AVERAGE NUMBER OF SHARES OUTSTANDING-BASIC (shares)	322.5	310.4
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (shares)	323.4	311.6
Electric
OPERATING REVENUES
Total operating revenues	$ 1,941	$ 1,877
Gas
OPERATING REVENUES
Total operating revenues	1,034	939
OPERATING EXPENSES
Operating costs	442	378
Steam
OPERATING REVENUES
Total operating revenues	321	314
Non-utility
OPERATING REVENUES
Total operating revenues	218	234
Power
OPERATING EXPENSES
Operating costs	368	353
Fuel
OPERATING EXPENSES
Operating costs	106	124
Other operations and maintenance
OPERATING EXPENSES
Operating costs	794	836
CECONY
OPERATING REVENUES
Total operating revenues	3,039	2,884
OPERATING EXPENSES
Depreciation and amortization	334	310
Taxes, other than income taxes	575	539
TOTAL OPERATING EXPENSES	2,313	2,179
OPERATING INCOME	726	705
OTHER INCOME (DEDUCTIONS)
Investment income	9	5
Allowance for equity funds used during construction	3	3
Other deductions	(19)	(39)
TOTAL OTHER INCOME (DEDUCTIONS)	(7)	(31)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	719	674
INTEREST EXPENSE
Interest on long-term debt	169	163
Other interest	17	5
Allowance for borrowed funds used during construction	(3)	(2)
NET INTEREST EXPENSE	183	166
INCOME BEFORE INCOME TAX EXPENSE	536	508
INCOME TAX EXPENSE	124	119
Net income for common stock	412	389
CECONY | Electric
OPERATING REVENUES
Total operating revenues	1,797	1,729
CECONY | Gas
OPERATING REVENUES
Total operating revenues	921	841
OPERATING EXPENSES
Operating costs	317	273
CECONY | Steam
OPERATING REVENUES
Total operating revenues	321	314
CECONY | Power
OPERATING EXPENSES
Operating costs	322	303
CECONY | Fuel
OPERATING EXPENSES
Operating costs	106	124
CECONY | Other operations and maintenance
OPERATING EXPENSES
Operating costs	$ 659	$ 630

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
NET INCOME	$ 445	$ 428
INCOME ATTRIBUTABLE TO NON-CONTROLLING INTEREST	(21)	0
NET INCOME	424	428
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	4	4
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	4	4
COMPREHENSIVE INCOME	428	432
CECONY
NET INCOME	412	389
OTHER COMPREHENSIVE INCOME, NET OF TAXES
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	0	0
COMPREHENSIVE INCOME	$ 412	$ 389

Consolidated Statement of Cash

Consolidated Statement of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Net income	$ 445	$ 428
Net income	424	428
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	413	348
Deferred income taxes	108	101
Rate case amortization and accruals	(29)	(28)
Common equity component of allowance for funds used during construction	(3)	(4)
Net derivative gains	10	(1)
Unbilled revenue and net unbilled revenue deferrals	11	48
Gain on sale of assets	(5)	0
Other non-cash items, net	(4)	(23)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(43)	(147)
Materials and supplies, including fuel oil and gas in storage	31	33
Other receivables and other current assets	(36)	26
Taxes receivable	0	18
Prepayments	(448)	(422)
Accounts payable	(108)	30
Pensions and retiree benefits obligations, net	93	84
Pensions and retiree benefits contributions	(4)	(184)
Accrued taxes	(19)	(61)
Accrued interest	97	68
Superfund and environmental remediation costs, net	(1)	(2)
Distributions from equity investments	14	35
System benefit charge	6	63
Deferred charges, noncurrent assets and other regulatory assets	(34)	(246)
Deferred credits and other regulatory liabilities	94	179
Other current and noncurrent liabilities	(124)	(200)
NET CASH FLOWS FROM OPERATING ACTIVITIES	464	143
INVESTING ACTIVITIES
Utility construction expenditures	(783)	(790)
Cost of removal less salvage	(72)	(63)
Non-utility construction expenditures	(48)	(35)
Investments in electric and gas transmission projects	(38)	(32)
Proceeds from sale of assets	48	0
Other investing activities	5	11
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(888)	(909)
FINANCING ACTIVITIES
Net issuance/(payment) of short-term debt	(1,131)	812
Issuance of long-term debt	825	0
Retirement of long-term debt	(11)	(10)
Debt issuance costs	(1)	(1)
Common stock dividends	(226)	(209)
Issuance of common shares - public offering	425	0
Issuance of common shares for stock plans	13	13
Distribution to noncontrolling interest	(2)	0
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	(108)	605
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(532)	(161)
BALANCE AT BEGINNING OF PERIOD	1,006	844
BALANCE AT END OF PERIOD	474	683
Cash paid/(received) during the period for:
Interest	130	124
Income taxes	3	(13)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	300	352
Issuance of common shares for dividend reinvestment	12	12
Software licenses acquired but unpaid as of end of period	100	0
CECONY
Net income	412	389
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	334	310
Deferred income taxes	122	108
Rate case amortization and accruals	(29)	(33)
Common equity component of allowance for funds used during construction	(3)	(3)
Unbilled revenue and net unbilled revenue deferrals	19	13
Gain on sale of assets	(5)	0
Other non-cash items, net	(11)	(10)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(36)	(126)
Materials and supplies, including fuel oil and gas in storage	24	24
Other receivables and other current assets	(24)	(8)
Accounts receivable from affiliated companies	(6)	(19)
Prepayments	(438)	(417)
Accounts payable	(75)	37
Accounts payable to affiliated companies	0	7
Pensions and retiree benefits obligations, net	87	80
Pensions and retiree benefits contributions	(3)	(183)
Accrued taxes	(18)	(68)
Accrued interest	72	68
Superfund and environmental remediation costs, net	(2)	(3)
System benefit charge	7	59
Accrued taxes to affiliated companies	0	3
Deferred charges, noncurrent assets and other regulatory assets	(47)	(202)
Deferred credits and other regulatory liabilities	92	161
Other current and noncurrent liabilities	(77)	(131)
NET CASH FLOWS FROM OPERATING ACTIVITIES	395	56
INVESTING ACTIVITIES
Utility construction expenditures	(728)	(747)
Cost of removal less salvage	(70)	(61)
Proceeds from sale of assets	48	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(750)	(808)
FINANCING ACTIVITIES
Net issuance/(payment) of short-term debt	(107)	763
Debt issuance costs	(1)	(1)
Capital contribution by parent	225	45
Dividend to parent	(228)	(211)
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	(111)	596
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(466)	(156)
BALANCE AT BEGINNING OF PERIOD	818	730
BALANCE AT END OF PERIOD	352	574
Cash paid/(received) during the period for:
Interest	101	93
Income taxes	8	18
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	267	272
Software licenses acquired but unpaid as of end of period	$ 95	$ 0

Consolidated Balance Sheet (Una

Consolidated Balance Sheet (Unaudited) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
CURRENT ASSETS
Cash and temporary cash investments	$ 406	$ 895
Accounts receivable - customers, less allowance for uncollectible accounts	1,309	1,267
Other receivables, less allowance for uncollectible accounts	267	285
Taxes receivable	49	49
Accrued unbilled revenue	500	514
Fuel oil, gas in storage, materials and supplies, at average cost	327	358
Prepayments	635	187
Regulatory assets	43	76
Restricted cash	68	111
Other current assets	177	122
TOTAL CURRENT ASSETS	3,781	3,864
INVESTMENTS	1,832	1,766
UTILITY PLANT, AT ORIGINAL COST
General	3,384	3,331
TOTAL	45,991	45,371
Less: Accumulated depreciation	9,953	9,769
Net	36,038	35,602
Construction work in progress	2,014	1,978
NET UTILITY PLANT	38,052	37,580
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	3,976	4,000
Construction work in progress	124	169
NET PLANT	42,152	41,749
OTHER NONCURRENT ASSETS
Goodwill	440	440
Intangible assets, less accumulated amortization of $53 and $29 in 2019 and 2018, respectively	1,630	1,654
Regulatory assets	4,245	4,294
Operating lease right-of-use asset	852	0
Other deferred charges and noncurrent assets	134	153
TOTAL OTHER NONCURRENT ASSETS	7,301	6,541
TOTAL ASSETS	55,066	53,920
CURRENT LIABILITIES
Long-term debt due within one year	2,029	650
Term loan	0	825
Notes payable	1,435	1,741
Accounts payable	1,010	1,187
Customer deposits	351	351
Accrued taxes	43	61
Accrued interest	226	129
Accrued wages	109	109
Fair value of derivative liabilities	46	50
Regulatory liabilities	152	114
System benefit charge	633	627
Operating lease liabilities	50	0
Other current liabilities	264	363
TOTAL CURRENT LIABILITIES	6,348	6,207
NONCURRENT LIABILITIES
Provision for injuries and damages	143	146
Pensions and retiree benefits	1,231	1,228
Superfund and other environmental costs	776	779
Asset retirement obligations	419	450
Fair value of derivative liabilities	51	16
Deferred income taxes and unamortized investment tax credits	5,951	5,820
Operating lease liabilities	825	0
Regulatory liabilities	4,613	4,641
Other deferred credits and noncurrent liabilities	275	299
TOTAL NONCURRENT LIABILITIES	14,284	13,379
LONG-TERM DEBT	16,933	17,495
EQUITY
Common shareholders’ equity	17,369	16,726
Noncontrolling interest	132	113
TOTAL EQUITY (See Statement of Equity)	17,501	16,839
TOTAL LIABILITIES AND EQUITY	55,066	53,920
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	30,704	30,378
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	9,329	9,100
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,574	2,562
CECONY
CURRENT ASSETS
Cash and temporary cash investments	352	818
Accounts receivable - customers, less allowance for uncollectible accounts	1,198	1,163
Other receivables, less allowance for uncollectible accounts	182	211
Taxes receivable	5	5
Accrued unbilled revenue	370	392
Accounts receivable from affiliated companies	220	214
Fuel oil, gas in storage, materials and supplies, at average cost	280	304
Prepayments	555	117
Regulatory assets	29	64
Other current assets	129	69
TOTAL CURRENT ASSETS	3,320	3,357
INVESTMENTS	407	385
UTILITY PLANT, AT ORIGINAL COST
General	3,100	3,056
TOTAL	43,070	42,508
Less: Accumulated depreciation	9,150	8,988
Net	33,920	33,520
Construction work in progress	1,894	1,850
NET UTILITY PLANT	35,814	35,370
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	3	4
NET PLANT	35,817	35,374
OTHER NONCURRENT ASSETS
Regulatory assets	3,895	3,923
Operating lease right-of-use asset	627	0
Other deferred charges and noncurrent assets	56	69
TOTAL OTHER NONCURRENT ASSETS	4,578	3,992
TOTAL ASSETS	44,122	43,108
CURRENT LIABILITIES
Long-term debt due within one year	475	475
Notes payable	1,085	1,192
Accounts payable	870	977
Accounts payable to affiliated companies	17	17
Customer deposits	339	339
Accrued taxes	38	55
Accrued interest	184	112
Accrued wages	99	99
Fair value of derivative liabilities	24	25
Regulatory liabilities	105	73
System benefit charge	576	569
Operating lease liabilities	41	0
Other current liabilities	201	267
TOTAL CURRENT LIABILITIES	4,054	4,200
NONCURRENT LIABILITIES
Provision for injuries and damages	137	141
Pensions and retiree benefits	969	952
Superfund and other environmental costs	691	693
Asset retirement obligations	295	292
Fair value of derivative liabilities	32	6
Deferred income taxes and unamortized investment tax credits	5,893	5,739
Operating lease liabilities	598	0
Regulatory liabilities	4,220	4,258
Other deferred credits and noncurrent liabilities	236	241
TOTAL NONCURRENT LIABILITIES	13,071	12,322
LONG-TERM DEBT	13,678	13,676
EQUITY
Common shareholders’ equity	13,319	12,910
TOTAL LIABILITIES AND EQUITY	44,122	43,108
CECONY | Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	28,903	28,595
CECONY | Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	8,493	8,295
CECONY | Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,574	$ 2,562

Consolidated Balance Sheet (U_2

Consolidated Balance Sheet (Unaudited) (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Accounts receivable - customers, allowance for uncollectible accounts	$ 63	$ 62
Other receivables, allowance for uncollectible accounts	7	5
Non-utility property, accumulated depreciation	296	275
Intangible assets, accumulated amortization	53	29
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	58	57
Other receivables, allowance for uncollectible accounts	6	3
Non-utility property, accumulated depreciation	$ 25	$ 25

Consolidated Statement of Equit

Consolidated Statement of Equity/Shareholder's Equity (Unaudited) - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Additional Paid-In Capital	Retained Earnings	Treasury Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Non- controlling Interest	CECONY	CECONYCommon Stock	CECONYAdditional Paid-In Capital	CECONYRetained Earnings	CECONYRepurchased Con Edison Stock	CECONYCapital Stock Expense	CECONYAccumulated Other Comprehensive Income/(Loss)
Beginning Balance (shares) at Dec. 31, 2017		310			23
Beginning Balance (shares) at Dec. 31, 2017										235
Beginning Balance at Dec. 31, 2017	$ 15,425	$ 34	$ 6,298	$ 10,235	$ (1,038)	$ (85)	$ (26)	$ 7							$ (6)
Beginning Balance at Dec. 31, 2017									$ 12,439	$ 589	$ 4,649	$ 8,231	$ (962)	$ (62)	(6)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	428			428
Net income	0
Net income	428								389			389
Common stock dividends	(221)			(221)					(211)			(211)
Issuance of common shares for stock plans (shares)		1
Issuance of common shares for stock plans	25		25
Capital contribution by parent									45		45
Other comprehensive income	4						4		0
Distributions to noncontrolling interest	0
Ending Balance (shares) at Mar. 31, 2018		311			23
Ending Balance (shares) at Mar. 31, 2018										235
Ending Balance at Mar. 31, 2018	15,661	$ 34	6,323	10,442	$ (1,038)	(85)	(22)	7							(6)
Ending Balance at Mar. 31, 2018									12,662	$ 589	4,694	8,409	(962)	(62)	(6)
Beginning Balance (shares) at Dec. 31, 2018		321			23
Beginning Balance (shares) at Dec. 31, 2018										235
Beginning Balance at Dec. 31, 2018	16,839	$ 34	7,117	10,728	$ (1,038)	(99)	(16)	113							(5)
Beginning Balance at Dec. 31, 2018	16,726								12,910	$ 589	4,769	8,581	(962)	(62)	(5)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	445			424
Net income	21							21
Net income	424								412			412
Common stock dividends	(237)			(237)					(228)			(228)
Issuance of common shares – public offering (shares)		6
Issuance of common shares – public offering	425		433			(8)
Issuance of common shares for stock plans	27		27
Capital contribution by parent									225		225
Other comprehensive income	4						4		0
Distributions to noncontrolling interest	(2)							(2)
Ending Balance (shares) at Mar. 31, 2019		327			23
Ending Balance (shares) at Mar. 31, 2019										235
Ending Balance at Mar. 31, 2019	17,501	$ 34	$ 7,577	$ 10,915	$ (1,038)	$ (107)	$ (12)	$ 132							(5)
Ending Balance at Mar. 31, 2019	$ 17,369								$ 13,319	$ 589	$ 4,994	$ 8,765	$ (962)	$ (62)	$ (5)

Consolidated Statement of Equ_2

Consolidated Statement of Equity/Shareholder's Equity (Unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement of Stockholders' Equity [Abstract]
Common stock dividends per share (dollars per share)	$ 0.74	$ 0.72

General

General	3 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
General	General These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Orange and Rockland Utilities, Inc. (O&R), Con Edison Clean Energy Businesses, Inc. (together with its subsidiaries, the Clean Energy Businesses) and Con Edison Transmission, Inc. (together with its subsidiaries, Con Edison Transmission) 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, 2018. Certain prior period amounts have been reclassified to conform to the current period presentation. Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiary, provides electric service in southeastern New York and northern New Jersey and gas service in southeastern New York. Con Edison Clean Energy Businesses, Inc. has three subsidiaries: Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company that provides energy-related products and services to retail customers. Con Edison Transmission, Inc. invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas).

Summary of Significant Accounti

Summary of Significant Accounting Policies and Other Matters	3 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
Summary of Significant Accounting Policies and Other Matters	Summary of Significant Accounting Policies and Other Matters Revenue Recognition The following table presents, for the three months ended March 31, 2019 , and 2018 revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source. For the Three Months Ended March 31, 2019 For the Three Months Ended March 31, 2018 (Millions of Dollars) Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues CECONY Electric $1,714 $83 $1,797 $1,771 $(42) $1,729 Gas 910 11 921 835 6 841 Steam 317 4 321 315 (1) 314 Total CECONY $2,941 $98 $3,039 $2,921 $(37) $2,884 O&R Electric 143 2 145 152 (3) 149 Gas 114 (1) 113 110 (13) 97 Total O&R $257 $1 $258 $262 $(16) $246 Clean Energy Businesses Renewables 106 (b) — 106 132 (b) — 132 Energy services 23 — 23 17 — 17 Other — 88 88 — 84 84 Total Clean Energy Businesses $129 $88 $217 $149 $84 $233 Con Edison Transmission 1 — 1 1 — 1 Other (c) — (1) (1) — — — Total Con Edison $3,328 $186 $3,514 $3,333 $31 $3,364 (a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans. For the Clean Energy Businesses, this includes revenue from wholesale services. (b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $2 million and $89 million for the three months ended March 31, 2019 and 2018 , respectively, of revenue related to engineering, procurement and construction services. (c) P arent company and consolidation adjustments. 2019 2018 (Millions of Dollars) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Beginning balance as of January 1, $29 $20 $58 $87 Additions (c) 24 — 36 32 Subtractions (c) 15 1 (d) 15 70 (d) Ending balance as of March 31, $38 $19 $79 $49 (a) Unbilled contract revenue represents accumulated incurred costs and earned profits on contracts (revenue arrangements), which have been recorded as revenue, but have not yet been billed to customers, and which represent contract assets as defined in Topic 606. Substantially all accrued unbilled contract revenue is expected to be collected within one year. Unbilled contract revenue arises from the cost-to-cost method of revenue recognition. Unbilled contract revenue from fixed-price type contracts is converted to billed receivables when amounts are invoiced to customers according to contractual billing terms, which generally occur when deliveries or other performance milestones are completed. (b) Unearned revenue represents a liability for billings to customers in excess of earned revenue, which are contract liabilities as defined in Topic 606. (c) Additions for unbilled contract revenue and subtractions for unearned revenue represent additional revenue earned. Additions for unearned revenue and subtractions for unbilled contract revenue represent billings. Activity also includes appropriate balance sheet classification for the period. (d) Of the subtractions from unearned revenue, $1 million and $48 million were included in the balance as of January 1, 2019 and 2018, respectively. As of March 31, 2019 , the aggregate amount of the remaining fixed performance obligations is $79 million , of which $43 million will be recognized within the next two years, and the remaining $36 million will be recognized pursuant to long-term service and maintenance agreements. Utility Plant General utility plant of Con Edison and CECONY included $98 million and $ 93 million , respectively, at March 31, 2019 and $100 million and $95 million , respectively, at December 31, 2018 , related to a May 2018 acquisition of software licenses. The estimated aggregate annual amortization expense related to the software licenses for Con Edison and CECONY is $7 million . The accumulated amortization for Con Edison and CECONY was $5 million at March 31, 2019 and was $3 million at December 31, 2018 . Long-Lived and Intangible Assets In January 2019, Pacific Gas and Electric Company (PG&E) filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code. The output of Con Edison Development renewable electric production projects with an aggregate of 680 MW (AC) of generating capacity (PG&E Projects) is sold to PG&E under long-term power purchase agreements (PG&E PPAs). Most of the PG&E PPAs have contract prices that are higher than estimated market prices. PG&E, as a debtor in possession, may assume or reject the PG&E PPAs, subject to review by the bankruptcy court or, pursuant to a January 2019 FERC order (which PG&E is challenging), the bankruptcy court and FERC. In a May 1, 2019 order, FERC denied PG&E’s request for a rehearing of the January 2019 order and reaffirmed its jurisdiction to review and approve the modification or abrogation of wholesale power contracts that are the subject of rejection in bankruptcy. The PG&E bankruptcy is an event of default under the PG&E PPAs. Unless the lenders for the related project debt otherwise agree, distributions from the related projects to Con Edison Development will not be made during the pendency of the bankruptcy. At March 31, 2019, Con Edison’s consolidated balance sheet included $859 million of net non-utility plant relating to the PG&E Projects, $1,108 million of intangible assets relating to the PG&E PPAs, $289 million of net non-utility plant of additional projects that secure the related project debt and $1,041 million of non-recourse related project debt. See "Long-term Debt" in Note C. Con Edison has tested whether its net non-utility plant relating to the PG&E Projects and intangible assets relating to the PG&E PPAs have been impaired. The projected future cash flows used in the test reflected Con Edison’s expectation that the PG&E PPAs are not likely to be rejected. Based on the test, Con Edison has determined that there was no impairment. If, in the future, one or more of the PG&E PPAs is rejected or any such rejection becomes likely, there will be an impairment of the related intangible assets and could be an impairment of the related non-utility plant. The amount of any such impairment could be material. Earnings Per Common Share Con Edison presents basic and diluted earnings per share (EPS) on the face of its consolidated income statement. Basic EPS is calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock. Potentially dilutive securities for Con Edison consist of restricted stock units and deferred stock units for which the average market price of the common shares for the period was greater than the exercise price. For the three months ended March 31, 2019 and 2018 , basic and diluted EPS for Con Edison are calculated as follows: For the Three Months Ended March 31, (Millions of Dollars, except per share amounts/Shares in Millions) 2019 2018 Net income for common stock $424 $428 Weighted average common shares outstanding – basic 322.5 310.4 Add: Incremental shares attributable to effect of potentially dilutive securities 0.9 1.2 Adjusted weighted average common shares outstanding – diluted 323.4 311.6 Net Income per common share – basic $1.31 $1.38 Net Income per common share – diluted $1.31 $1.37 The computation of diluted EPS for the three months ended March 31, 2019 and 2018 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect. Changes in Accumulated Other Comprehensive Income/(Loss) by Component For the three months ended March 31, 2019 and 2018 , changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Beginning balance, accumulated OCI, net of taxes (a) $(16) $(26) $(5) $(6) OCI before reclassifications, net of tax of $(1) for Con Edison in 2019 and 2018 2 3 — — Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2018 (a)(b) 2 1 — — Current period OCI, net of taxes 4 4 — — Ending balance, accumulated OCI, net of taxes $(12) $(22) $(5) $(6) (a) Tax reclassified from accumulated OCI is reported in the income tax expense line item of the consolidated income statement. (b) For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of total periodic pension and other postretirement benefit cost. See Notes E and F. Reconciliation of Cash, Temporary Cash Investments and Restricted Cash Cash, temporary cash investments and restricted cash are presented on a combined basis in the Companies’ consolidated statements of cash flows. At March 31, 2019 and 2018 , cash, temporary cash investments and restricted cash for Con Edison and CECONY are as follows: At March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Cash and temporary cash investments $406 $651 $352 $574 Restricted cash (a) 68 32 — — Total cash, temporary cash investments and restricted cash $474 $683 $352 $574 (a) Restricted cash included cash of Con Edison Development renewable electric production project subsidiaries ( $67 million and $31 million at March 31, 2019 and 2018 , respectively) that, under the related project debt agreements, is restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves. During the pendency of the PG&E bankruptcy, unless the lenders for the related project debt otherwise agree, cash may not be distributed from the related projects to Con Edison Development. See “Long-Lived and Intangible Assets,” above, and Note C. In addition, restricted cash includes O&R's New Jersey utility subsidiary, Rockland Electric Company transition bond charge collections, net of principal, interest, trustee and service fees ( $1 million at March 31, 2019 and 2018 ) that are restricted until the bonds mature in 2019 .

Regulatory Matters

Regulatory Matters	3 Months Ended
	Mar. 31, 2019
Regulated Operations [Abstract]
Regulatory Matters	Regulatory Matters Rate Plans CECONY – Electric In April 2019, CECONY preliminarily updated its January 2019 request to the New York State Public Service Commission (NYSPSC) for an electric rate increase effective January 2020. The company decreased its requested January 2020 rate increase by $12 million to $473 million , increased its illustrated January 2021 rate increase by $7 million to $359 million and decreased its illustrated January 2022 rate increase by $14 million to $249 million . CECONY – Gas In April 2019, CECONY preliminarily updated its January 2019 request to the NYSPSC for a gas rate increase effective January 2020. The company decreased its requested January 2020 rate increase by $9 million to $201 million , decreased its illustrated January 2021 rate increase by $14 million to $124 million and decreased its illustrated January 2022 rate increase by $1 million to $154 million . O&R New York – Electric and Gas In March 2019, the NYSPSC approved the November 2018 joint proposal for new electric and gas rates. The joint proposal provides for electric rate increases of $13.4 million , $8.0 million and $5.8 million , effective January 1, 2019, 2020 and 2021, respectively. The joint proposal provides for a gas rate decrease of $7.5 million , effective January 1, 2019, and gas rate increases of $3.6 million and $0.7 million , effective January 1, 2020 and 2021. Other Regulatory Matters In August and November 2017, the NYSPSC issued orders in its proceeding investigating an April 21, 2017 Metropolitan Transportation Authority (MTA) subway power outage. The orders indicated that the investigation determined that the outage was caused by a failure of CECONY’s electricity supply to a subway station, which led to a loss of the subway signals, and that one of the secondary services to the MTA facility had been improperly rerouted and was not properly documented by the company. The orders also indicated that the loss of power to the subway station affected multiple subway lines and caused widespread delays across the subway system. Pursuant to the orders, the company is required to take certain actions, including inspecting, repairing and installing certain electrical equipment that serves the subway system, analyzing power supply and power quality events affecting the MTA’s signaling services, and filing monthly reports with the NYSPSC on all of the company's activities related to the subway system. The company completed the required actions in 2018. Through March 31, 2019 , the company incurred costs related to this matter of $270 million . Included in this amount is $31 million in capital and operating and maintenance costs reflected in the company's electric rate plan and $239 million deferred as a regulatory asset that the company is seeking to recover in its pending electric rate proceeding. The company is unable to estimate the amount or range of its possible loss related to this matter. At March 31, 2019, the company had not accrued a liability related to this matter. In August 2018, the NYSPSC ordered CECONY to begin on January 1, 2019 to credit the company's electric and gas customers, and to begin on October 1, 2018 to credit its steam customers, with the net benefits of the federal Tax Cuts and Jobs Act of 2017 (TCJA) as measured based on amounts reflected in its rate plans prior to the enactment of the TCJA in December 2017. The net benefits include the revenue requirement impact of the reduction in the corporate federal income tax rate to 21 percent, the elimination for utilities of bonus depreciation and the amortization of excess deferred federal income taxes. CECONY estimates that its credit of net benefits of the TCJA to its electric, gas and steam customers in 2019 will amount to $259 million , $113 million and $25 million , respectively. CECONY’s net benefits prior to January 1, 2019 allocable to the company’s electric customers ( $311 million ) are to be deferred and addressed in its pending electric rate proceeding. CECONY’s net benefits prior to January 1, 2019 allocable to the company’s gas customers ( $90 million ) and net benefits prior to October 1, 2018 allocable to the company’s steam customers ( $15 million ) are to be amortized over a three -year period. CECONY’s net regulatory liability for future income taxes, including both the protected and unprotected portions, allocable to the company’s electric customers ( $2,489 million ) is to continue to be deferred and addressed in its pending electric rate proceeding and the amounts allocable to its gas and steam customers ( $804 million and $185 million , respectively) are to be amortized over the remaining lives of the related assets (with the amortization period for the unprotected portion subject to review in its pending gas rate proceeding and next steam rate proceeding). In January 2018, the NYSPSC issued an order initiating a focused operations audit of the income tax accounting of certain utilities, including CECONY and O&R. The Utilities are unable to estimate the amount or range of their possible loss related to this matter. At March 31, 2019, the Utilities had not accrued a liability related to this matter. In March 2018, Winter Storms Riley and Quinn caused damage to the Utilities’ electric distribution systems and interrupted service to approximately 209,000 CECONY customers, 93,000 O&R customers and 44,000 RECO customers. At March 31, 2019 , CECONY's costs related to March 2018 storms, including Riley and Quinn, amounted to $133 million , including operation and maintenance expenses reflected in its electric rate plan ( $15 million ), operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan ( $84 million ), capital expenditures ( $29 million ) and removal costs ( $6 million ). At March 31, 2019 , O&R and RECO costs related to 2018 storms amounted to $43 million and $17 million , respectively, most of which were deferred as regulatory assets pursuant to their electric rate plans. The NYSPSC investigated the preparation and response to the storms by CECONY, O&R, and other New York electric utilities, including all aspects of their emergency response plans. In April 2019, following the issuance of a NYSPSC staff report on the investigation, the NYSPSC ordered the utilities to show cause why the NYSPSC should not commence a penalty action against them for violating their emergency response plans. The Utilities are unable to estimate the amount or range of their possible loss related to this matter. At March 31, 2019, the Utilities had not accrued a liability related to this matter. In May 2018, FERC denied a complaint the NJBPU filed with FERC seeking the re-allocation to CECONY of certain PJM Interconnection LLC (PJM) transmission costs that had been allocated to the company prior to April 2017 when transmission service provided to the company pursuant to the PJM open access transmission tariff terminated. The transmission service terminated because the company did not exercise its option to continue the service following a series of requests PJM had submitted to FERC that substantially increased the charges for the transmission service. CECONY challenged each of these requests. FERC rejected all but one of CECONY’s protests. In June 2015 and May 2016, CECONY filed appeals of certain FERC decisions with the U.S. Court of Appeals. In July 2018, FERC established a settlement proceeding relating to the allocation of PJM transmission costs. Under CECONY’s electric rate plan, unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. In July 2018, the NYSPSC commenced an investigation into the rupture of a CECONY steam main (see Note H). In March 2019, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence a penalty action and prudence proceeding against CECONY for alleged violations of gas operator qualification, performance, and inspection requirements. The company is seeking to resolve this matter through settlement negotiations with the NYSPSC staff. Any settlement would be subject to NYSPSC approval. The company is unable to estimate the amount or range of its possible loss related to this matter. At March 31, 2019, the company had not accrued a liability related to this matter. Regulatory Assets and Liabilities Regulatory assets and liabilities at March 31, 2019 and December 31, 2018 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Regulatory assets Unrecognized pension and other postretirement costs $2,166 $2,238 $2,052 $2,111 Environmental remediation costs 798 810 706 716 Revenue taxes 299 291 286 278 MTA power reliability deferral 239 229 239 229 Property tax reconciliation 114 101 101 86 Deferred storm costs 77 76 — — Municipal infrastructure support costs 75 67 75 67 Pension and other postretirement benefits deferrals 63 73 45 56 System peak reduction and energy efficiency programs 60 72 59 70 Deferred derivative losses 43 17 37 11 Brooklyn Queens demand management program 37 39 37 39 Meadowlands heater odorization project 36 36 36 36 Unamortized loss on reacquired debt 34 36 32 34 Preferred stock redemption 23 23 23 23 Recoverable REV demonstration project costs 20 20 18 18 Gate station upgrade project 18 17 18 17 Indian Point Energy Center program costs 7 13 7 13 Workers’ compensation 6 5 6 5 O&R transition bond charges 1 2 — — Other 129 129 118 114 Regulatory assets – noncurrent 4,245 4,294 3,895 3,923 Deferred derivative losses 39 36 29 29 Recoverable energy costs 4 40 — 35 Regulatory assets – current 43 76 29 64 Total Regulatory Assets $4,288 $4,370 $3,924 $3,987 Regulatory liabilities Future income tax $2,496 $2,515 $2,347 $2,363 Allowance for cost of removal less salvage 934 928 795 790 TCJA net benefits* 438 434 417 411 Energy efficiency portfolio standard unencumbered funds 124 127 119 122 Net unbilled revenue deferrals 115 117 115 117 Pension and other postretirement benefit deferrals 62 62 38 40 Net proceeds from sale of property 46 6 46 6 Property tax refunds 45 45 45 45 System benefit charge carrying charge 31 27 28 24 Settlement of prudence proceeding 29 37 29 37 Property tax reconciliation 26 36 26 36 BQDM and REV Demo reconciliations 20 18 20 18 Earnings sharing - electric, gas and steam 19 36 10 27 Carrying charges on repair allowance and bonus depreciation 15 21 14 21 Settlement of gas proceedings 15 15 15 15 New York State income tax rate change 12 17 12 17 Unrecognized other postretirement costs 11 7 6 7 Base rate change deferrals 7 10 7 10 Other 168 183 131 152 Regulatory liabilities – noncurrent 4,613 4,641 4,220 4,258 Revenue decoupling mechanism 34 53 22 36 Refundable energy costs 83 31 51 8 Deferred derivative gains 35 30 32 29 Regulatory liabilities – current 152 114 105 73 Total Regulatory Liabilities $4,765 $4,755 $4,325 $4,331 * See "Other Regulatory Matters," above.

Capitalization

Capitalization	3 Months Ended
	Mar. 31, 2019
Debt Disclosure [Abstract]
Capitalization	Capitalization In February 2019, Con Edison borrowed $825 million under a two -year variable-rate term loan to fund the repayment of a 6-month variable-rate term loan. In March 2019, Con Edison issued 5,649,369 shares of its common stock for $425 million upon physical settlement of the remaining shares subject to its November 2018 forward sale agreements. The carrying amounts and fair values of long-term debt at March 31, 2019 and December 31, 2018 were: (Millions of Dollars) 2019 2018 Long-Term Debt (including current portion) (a) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $18,962 $20,304 $18,145 $18,740 CECONY $14,153 $15,371 $14,151 $14,685 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $181 million and $137 million for Con Edison and CECONY, respectively, as of March 31, 2019 and $185 million and $139 million for Con Edison and CECONY, respectively, as of December 31, 2018 . The fair values of the Companies' long-term debt have been estimated primarily using available market information and at March 31, 2019 are classified as Level 2 (see Note M). At December 31, 2018, the Clean Energy Businesses had $2,076 million of non-recourse project debt secured by the pledge of the applicable renewable energy production projects, of which $1,965 million was included in long-term debt and $111 million was included in long-term debt due within one year in Con Edison's consolidated balance sheet. As a result of the January 2019 PG&E bankruptcy (see "Long-Lived and Intangible Assets" in Note A), during the first quarter of 2019, Con Edison reclassified on its consolidated balance sheet the PG&E-related project debt that was included in long-term debt to long-term debt due within one year. At March 31, 2019, long-term debt due within one year included $1,041 million of PG&E-related project debt. The lenders for the PG&E-related project debt may, upon written notice, declare principal and interest on the PG&E-related project debt to be due and payable immediately and, if such amounts are not timely paid, foreclose on the related projects. The company is seeking to negotiate agreements with the PG&E-related project debt lenders pursuant to which the lenders would defer exercising these remedies.

Short-Term Borrowing

Short-Term Borrowing	3 Months Ended
	Mar. 31, 2019
Debt Disclosure [Abstract]
Short-Term Borrowing	Short-Term Borrowing At March 31, 2019 , Con Edison had $1,435 million of commercial paper outstanding of which $1,085 million was outstanding under CECONY’s program. The weighted average interest rate at March 31, 2019 was 2.7 percent for both Con Edison and CECONY. At December 31, 2018 , Con Edison had $1,741 million of commercial paper outstanding of which $1,192 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2018 was 3.0 percent for both Con Edison and CECONY. At March 31, 2019 and December 31, 2018 , no loans were outstanding under the Companies' December 2016 credit agreement (Credit Agreement). An immaterial amount of letters of credit were outstanding under the Credit Agreement as of March 31, 2019 and December 31, 2018 . In April 2019, the termination date of the Credit Agreement was extended from December 2022 to December 2023 with respect to banks with aggregate commitments of $2,200 million .

Pension Benefits

Pension Benefits	3 Months Ended
	Mar. 31, 2019
Retirement Benefits [Abstract]
Pension Benefits	Pension Benefits Total Periodic Benefit Cost The components of the Companies’ total periodic benefit cost for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Service cost – including administrative expenses $62 $72 $58 $68 Interest cost on projected benefit obligation 150 140 141 131 Expected return on plan assets (247) (258) (234) (245) Recognition of net actuarial loss 130 172 123 163 Recognition of prior service cost/(credit) (4) (4) (5) (5) TOTAL PERIODIC BENEFIT COST $91 $122 $83 $112 Cost capitalized (26) (31) (24) (29) Reconciliation to rate level (5) (23) (4) (25) Total expense recognized $60 $68 $55 $58 Components of net periodic benefit cost other than service cost are presented outside of operating income on the Companies' consolidated income statements, and only the service cost component is eligible for capitalization. Accordingly, the service cost component is included in the line "Other operations and maintenance" and the non-service cost components are included in the line "Other deductions" in the Companies' consolidated income statements. Expected Contributions Based on estimates as of March 31, 2019 , the Companies expect to make contributions to the pension plans during 2019 of $350 million (of which $318 million is to be made by CECONY). The Companies’ policy is to fund the total periodic benefit cost of the qualified plan to the extent tax deductible and to also contribute to the non-qualified supplemental plans. During the first three months of 2019, the Companies contributed $4 million to the pension plans, of which $3 million was made by CECONY.

Other Postretirement Benefits

Other Postretirement Benefits	3 Months Ended
	Mar. 31, 2019
Retirement Benefits [Abstract]
Other Postretirement Benefits	Other Postretirement Benefits Total Periodic Benefit Cost The components of the Companies’ total periodic other postretirement benefit cost/(credit) for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Service cost $4 $5 $3 $3 Interest cost on accumulated other postretirement benefit obligation 11 11 9 9 Expected return on plan assets (16) (18) (14) (16) Recognition of net actuarial loss/(gain) (2) 2 (2) 1 Recognition of prior service cost/(credit) (1) (2) — (1) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT) $(4) $(2) $(4) $(4) Cost capitalized (2) (2) (2) (2) Reconciliation to rate level 3 2 2 3 Total expense/(credit) recognized $(3) $(2) $(4) $(3) For information about the presentation of the components of other postretirement benefit costs, see Note E. Contributions Based on estimates as of March 31, 2019 , Con Edison and CECONY expect to make contributions of $10 million (of which $7 million is to be made by CECONY) to the other postretirement benefit plans in 2019. The Companies' policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

Environmental Matters

Environmental Matters	3 Months Ended
	Mar. 31, 2019
Environmental Remediation Obligations [Abstract]
Environmental Matters	Environmental Matters Superfund Sites Hazardous substances, such as asbestos, polychlorinated biphenyls (PCBs) and coal tar, have been used or generated in the course of operations of the Utilities and their predecessors and are present at sites and in facilities and equipment they currently or previously owned, including sites at which gas was manufactured or stored. The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances for investigation and remediation costs (which include costs of demolition, removal, disposal, storage, replacement, containment and monitoring) and natural resource damages. Liability under these laws can be material and may be imposed for contamination from past acts, even though such past acts may have been lawful at the time they occurred. The sites at which the Utilities have been asserted to have liability under these laws, including their manufactured gas plant sites and any neighboring areas to which contamination may have migrated, are referred to herein as “Superfund Sites.” For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of the undiscounted cost to investigate the sites and, for sites that have been investigated in whole or in part, the cost to remediate the sites, if remediation is necessary and if a reasonable estimate of such cost can be made. Remediation costs are estimated in light of the information available, applicable remediation standards and experience with similar sites. The accrued liabilities and regulatory assets related to Superfund Sites at March 31, 2019 and December 31, 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Accrued Liabilities: Manufactured gas plant sites $687 $689 $602 $603 Other Superfund Sites 89 90 89 90 Total $776 $779 $691 $693 Regulatory assets $798 $810 $706 $716 Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) prudently incurred site investigation and remediation costs. Environmental remediation costs incurred related to Superfund Sites for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Remediation costs incurred $3 $3 $2 $3 Insurance and other third-party recoveries received by Con Edison or CECONY were immaterial for the three months ended March 31, 2019 and 2018 . In 2018, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $2.8 billion and $2.6 billion, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different. Asbestos Proceedings Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, which are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At March 31, 2019 , Con Edison and CECONY have accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. These estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Courts have begun, and unless otherwise determined on appeal may continue, to apply different standards for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims. The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at March 31, 2019 and December 31, 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $80 $79 $76 $75 Regulatory assets – workers’ compensation $6 $5 $6 $5

Other Material Contingencies

Other Material Contingencies	3 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Other Material Contingencies	10 years Total (Millions of Dollars) Con Edison Transmission $539 $337 $— $876 Energy transactions 490 19 200 709 Renewable electric production projects 142 — 402 544 Other 70 — — 70 Total $1,241 $356 $602 $2,199 Con Edison Transmission — Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric acquired a 45.7 percent interest in NY Transco when it was formed in 2014. In May 2016, the transmission owners transferred certain projects to NY Transco, for which CET Electric made its required contributions. NY Transco has proposed other transmission projects in the New York Independent System Operator's competitive bidding process. These other projects are subject to certain authorizations from the NYSPSC, the FERC and, as applicable, other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of CET Electric’s contributions for these other projects as calculated based on the assumptions that the projects are completed at 175 percent of their estimated costs and NY Transco does not use any debt financing for the projects. Guarantee term shown is assumed as the selection of the projects and resulting timing of the contributions is not certain. Also included within the table above are guarantees for $124 million from Con Edison on behalf of CET Gas in relation to Mountain Valley Pipeline (MVP), LLC, a company developing a proposed gas transmission project in West Virginia and Virginia. Energy Transactions — Con Edison guarantees payments on behalf of the Clean Energy Businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Renewable Electric Production Projects — Con Edison, Con Edison Development, and Con Edison Solutions guarantee payments on behalf of their wholly-owned subsidiaries associated with their investment in, or development for others of, solar and wind energy facilities. Other — Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with operation of solar energy facilities and energy service projects of Con Edison Development and Con Edison Solutions, respectively." id="sjs-B4">Other Material Contingencies Manhattan Explosion and Fire On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116 th and 117 th Streets in Manhattan were destroyed by an explosion and fire. CECONY had delivered gas to the buildings through service lines from a distribution main located below ground on Park Avenue. Eight people died and more than 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC. In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. In February 2017, the NYSPSC approved a settlement agreement with the company related to the NYSPSC's investigations of the incident and the practices of qualifying persons to perform plastic fusions. Pursuant to the agreement, the company is providing $27 million of future benefits to customers (for which it has accrued a regulatory liability) and will not recover from customers $126 million of costs for gas emergency response activities that it had previously incurred and expensed. Approximately eighty suits are pending against the company seeking generally unspecified damages and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have for damages in connection with the incident. The company is unable to estimate the amount or range of its possible loss for damages related to the incident. At March 31, 2019 , the company had not accrued a liability for damages related to the incident. Manhattan Steam Main Rupture In July 2018, a CECONY steam main located on Fifth Avenue and 21 st Street in Manhattan ruptured. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of buildings and streets for various periods. The NYSPSC has commenced an investigation. As of March 31, 2019 , with respect to the incident, the company incurred estimated operating costs of $16 million for property damage, clean- up and other response costs and invested $9 million in capital and retirement costs. The company has notified its insurers of the incident and believes that the policies currently in force will cover the company’s costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have for damages to others in connection with the incident. The company is unable to estimate the amount or range of its possible loss related to the incident. At March 31, 2019 , the company had not accrued a liability related to the incident. Other Contingencies For information about the PG&E bankruptcy, see "Long-Lived and Intangible Assets" in Note A and Note C. Also, for additional contingencies, see "Other Regulatory Matters" in Note B and “Uncertain Tax Positions” in Note J. Guarantees Con Edison and its subsidiaries have entered into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison under these agreements totaled $2,199 million and $2,439 million at March 31, 2019 and December 31, 2018 , respectively. A summary, by type and term, of Con Edison’s total guarantees under these agreements at March 31, 2019 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) Con Edison Transmission $539 $337 $— $876 Energy transactions 490 19 200 709 Renewable electric production projects 142 — 402 544 Other 70 — — 70 Total $1,241 $356 $602 $2,199 Con Edison Transmission — Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric acquired a 45.7 percent interest in NY Transco when it was formed in 2014. In May 2016, the transmission owners transferred certain projects to NY Transco, for which CET Electric made its required contributions. NY Transco has proposed other transmission projects in the New York Independent System Operator's competitive bidding process. These other projects are subject to certain authorizations from the NYSPSC, the FERC and, as applicable, other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of CET Electric’s contributions for these other projects as calculated based on the assumptions that the projects are completed at 175 percent of their estimated costs and NY Transco does not use any debt financing for the projects. Guarantee term shown is assumed as the selection of the projects and resulting timing of the contributions is not certain. Also included within the table above are guarantees for $124 million from Con Edison on behalf of CET Gas in relation to Mountain Valley Pipeline (MVP), LLC, a company developing a proposed gas transmission project in West Virginia and Virginia. Energy Transactions — Con Edison guarantees payments on behalf of the Clean Energy Businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Renewable Electric Production Projects — Con Edison, Con Edison Development, and Con Edison Solutions guarantee payments on behalf of their wholly-owned subsidiaries associated with their investment in, or development for others of, solar and wind energy facilities. Other — Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with operation of solar energy facilities and energy service projects of Con Edison Development and Con Edison Solutions, respectively.

Leases

Leases	3 Months Ended
	Mar. 31, 2019
Leases [Abstract]
Leases	Leases In January 2019, the Companies adopted Accounting Standards Update (ASU) No. 2016-02, “Leases (Topic 842),” including the amendments thereto, using a modified retrospective transition method of adoption that required no prior period adjustments or charges to retained earnings for cumulative impact. The standard supersedes the lease requirements within ASC Topic 840, “Leases.” The Companies lease electric transmission facilities, gas distribution facilities, land, office buildings and equipment. Upon adoption of Topic 842, the Companies recognized lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment (with the amortization of the lease asset based on the rental payments recovered from our customers) and to account the same way for finance leases. Lessor accounting is similar to the previous model, but updated to align with ASC Topic 606 “Revenue from Contracts with Customers." The Companies elected the following practical expedients: (1) a package of practical expedients that allows the Companies to not reassess: (a) whether expired or existing contracts contained leases; (b) the lease classification for expired or existing leases and (c) the initial direct costs for existing leases; (2) for all underlying asset classes, an expedient that allows the Companies to not apply the recognition requirements to short-term leases and an expedient that will allow the Companies to account for lease and associated non-lease components as a single lease component; (3) an expedient that allows the use of hindsight to determine lease term; and (4) an expedient that allows the Companies to not evaluate under Topic 842 land easements that exist or expired before the entity’s adoption of Topic 842 and that were not previously accounted for as leases under Topic 840. The Companies, upon adoption of Topic 842 recognized, and for new operating leases at commencement date recognize, operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 35 years , and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms may include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. Operating lease cost and cash paid for amounts included in the measurement of lease liabilities were as follows for Con Edison and CECONY for the three months ended March 31, 2019 : (Millions of Dollars) Con Edison CECONY Operating lease cost $21 $16 Operating lease cash flows $8 $4 As of March 31, 2019 , assets recorded as finance leases for Con Edison and CECONY were $2 million and $1 million , respectively, and the accumulated depreciation associated with finance leases for Con Edison and CECONY were $4 million and $3 million , respectively. For the three months ended March 31, 2019 , finance lease costs and cash flows for Con Edison and CECONY were immaterial. Right-of-use assets obtained in exchange for lease obligations were immaterial for Con Edison and CECONY for the three months ended March 31, 2019 . Other information related to leases for Con Edison and CECONY at March 31, 2019 was as follows: Con Edison CECONY Weighted Average Remaining Lease Term: Operating leases 19.3 years 14.7 years Finance leases 10.0 years 2.5 years Weighted Average Discount Rate: Operating leases 4.3% 3.6% Finance leases 4.2% 5.3% Future minimum lease payments under non-cancellable leases at March 31, 2019 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending March 31, Operating Leases Finance Leases Operating Leases Finance Leases 2020 $79 $1 $58 $1 2021 74 — 58 — 2022 71 — 55 — 2023 69 — 53 — 2024 68 — 53 — All years thereafter 973 1 553 — Total future minimum lease payments $1,334 $2 $830 $1 Less: imputed interest (459) — (191) — Total $875 $2 $639 $1 Reported as of March 31, 2019 Operating lease liabilities (current) $50 $— $41 $— Operating lease liabilities (noncurrent) 825 — 598 — Other current liabilities — 1 — 1 Other noncurrent liabilities — 1 — — Total $875 $2 $639 $1 At March 31, 2019 , the Companies do not have material obligations under operating or finance leases that have not yet commenced. The future minimum lease commitments at December 31, 2018, accounted for under Topic 840, for the Companies’ operating lease agreements that are not cancellable by the Companies were as follows: (Millions of Dollars) Con Edison CECONY 2019 $72 $56 2020 72 56 2021 71 54 2022 68 53 2023 68 53 All years thereafter 890 592 Total $1,241 $864 The Companies are lessors under certain leases whereby the Companies own real estate and lease portions of it to others. Revenue under such leases was immaterial for Con Edison and CECONY for the three months ended March 31, 2019 .
Leases	Leases In January 2019, the Companies adopted Accounting Standards Update (ASU) No. 2016-02, “Leases (Topic 842),” including the amendments thereto, using a modified retrospective transition method of adoption that required no prior period adjustments or charges to retained earnings for cumulative impact. The standard supersedes the lease requirements within ASC Topic 840, “Leases.” The Companies lease electric transmission facilities, gas distribution facilities, land, office buildings and equipment. Upon adoption of Topic 842, the Companies recognized lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment (with the amortization of the lease asset based on the rental payments recovered from our customers) and to account the same way for finance leases. Lessor accounting is similar to the previous model, but updated to align with ASC Topic 606 “Revenue from Contracts with Customers." The Companies elected the following practical expedients: (1) a package of practical expedients that allows the Companies to not reassess: (a) whether expired or existing contracts contained leases; (b) the lease classification for expired or existing leases and (c) the initial direct costs for existing leases; (2) for all underlying asset classes, an expedient that allows the Companies to not apply the recognition requirements to short-term leases and an expedient that will allow the Companies to account for lease and associated non-lease components as a single lease component; (3) an expedient that allows the use of hindsight to determine lease term; and (4) an expedient that allows the Companies to not evaluate under Topic 842 land easements that exist or expired before the entity’s adoption of Topic 842 and that were not previously accounted for as leases under Topic 840. The Companies, upon adoption of Topic 842 recognized, and for new operating leases at commencement date recognize, operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 35 years , and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms may include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. Operating lease cost and cash paid for amounts included in the measurement of lease liabilities were as follows for Con Edison and CECONY for the three months ended March 31, 2019 : (Millions of Dollars) Con Edison CECONY Operating lease cost $21 $16 Operating lease cash flows $8 $4 As of March 31, 2019 , assets recorded as finance leases for Con Edison and CECONY were $2 million and $1 million , respectively, and the accumulated depreciation associated with finance leases for Con Edison and CECONY were $4 million and $3 million , respectively. For the three months ended March 31, 2019 , finance lease costs and cash flows for Con Edison and CECONY were immaterial. Right-of-use assets obtained in exchange for lease obligations were immaterial for Con Edison and CECONY for the three months ended March 31, 2019 . Other information related to leases for Con Edison and CECONY at March 31, 2019 was as follows: Con Edison CECONY Weighted Average Remaining Lease Term: Operating leases 19.3 years 14.7 years Finance leases 10.0 years 2.5 years Weighted Average Discount Rate: Operating leases 4.3% 3.6% Finance leases 4.2% 5.3% Future minimum lease payments under non-cancellable leases at March 31, 2019 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending March 31, Operating Leases Finance Leases Operating Leases Finance Leases 2020 $79 $1 $58 $1 2021 74 — 58 — 2022 71 — 55 — 2023 69 — 53 — 2024 68 — 53 — All years thereafter 973 1 553 — Total future minimum lease payments $1,334 $2 $830 $1 Less: imputed interest (459) — (191) — Total $875 $2 $639 $1 Reported as of March 31, 2019 Operating lease liabilities (current) $50 $— $41 $— Operating lease liabilities (noncurrent) 825 — 598 — Other current liabilities — 1 — 1 Other noncurrent liabilities — 1 — — Total $875 $2 $639 $1 At March 31, 2019 , the Companies do not have material obligations under operating or finance leases that have not yet commenced. The future minimum lease commitments at December 31, 2018, accounted for under Topic 840, for the Companies’ operating lease agreements that are not cancellable by the Companies were as follows: (Millions of Dollars) Con Edison CECONY 2019 $72 $56 2020 72 56 2021 71 54 2022 68 53 2023 68 53 All years thereafter 890 592 Total $1,241 $864 The Companies are lessors under certain leases whereby the Companies own real estate and lease portions of it to others. Revenue under such leases was immaterial for Con Edison and CECONY for the three months ended March 31, 2019 .

Income Tax

Income Tax	3 Months Ended
	Mar. 31, 2019
Income Tax Disclosure [Abstract]
Income Tax	Income Tax Con Edison’s income tax expense decreased to $108 million for the three months ended March 31, 2019 from $117 million for the three months ended March 31, 2018 . The decrease in income tax expense is primarily due to lower income before income tax expense (excluding income attributable to noncontrolling interest (see Note N)), an increase in the amortization of excess deferred federal income taxes due to the TCJA and higher renewable energy credits, offset in part by higher state income taxes. CECONY’s income tax expense increased to $124 million for the three months ended March 31, 2019 from $119 million for the three months ended March 31, 2018 . The increase in income tax expense is primarily due to higher income before income tax expense and higher state income taxes, offset in part by an increase in the amortization of excess deferred federal income taxes due to the TCJA . Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes for the three months ended March 31, is as follows: Con Edison CECONY (% of Pre-tax income) 2019 2018 2019 2018 STATUTORY TAX RATE Federal 21 % 21 % 21 % 21 % Changes in computed taxes resulting from: State income tax 5 4 6 5 Cost of removal 1 1 1 1 Other plant-related items (1 ) — — (1 ) Renewable energy credits (1 ) (1 ) — — Amortization of excess deferred federal income taxes (4 ) (3 ) (4 ) (3 ) Other (1 ) (1 ) (1 ) — Effective tax rate 20 % 21 % 23 % 23 % CECONY, O&R and RECO deferred as regulatory liabilities their estimated net benefits under the TCJA for the three months ended March 31, 2018 . CECONY continued to defer its estimated net benefits for its electric service for the three months ended March 31, 2019. The net benefits include the revenue requirement impact of the reduction in the corporate federal income tax rate to 21 percent, the elimination for utilities of bonus depreciation and the amortization of excess deferred federal income taxes the utilities collected from customers that will not need to be paid to the Internal Revenue Service under the TCJA. See “Other Regulatory Matters” in Note B. Uncertain Tax Positions At March 31, 2019 , the estimated liability for uncertain tax positions for Con Edison was $7 million ( $4 million for CECONY). Con Edison reasonably expects to resolve within the next twelve months approximately $4 million of various federal and state uncertainties due to the expected completion of ongoing tax examinations and resolution of state refund claims, of which the entire amount, if recognized, would reduce Con Edison's effective tax rate. The amount related to CECONY is approximately $2 million , which, if recognized, would reduce CECONY’s effective tax rate. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is $7 million ( $6 million , net of federal taxes). The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In the three months ended March 31, 2019 , the Companies recognized no interest expense or penalties for uncertain tax positions in their consolidated income statements. At March 31, 2019 and December 31, 2018 , the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

Financial Information by Busine

Financial Information by Business Segment	3 Months Ended
	Mar. 31, 2019
Segment Reporting [Abstract]
Financial Information by Business Segment	Financial Information by Business Segment Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. The financial data for the business segments for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Operating revenues Inter-segment revenues Depreciation and amortization Operating income/(loss) (Millions of Dollars) 2019 2018 2019 2018 2019 2018 2019 2018 CECONY Electric $1,797 $1,729 $4 $4 $257 $240 $257 $254 Gas 921 841 2 1 55 49 344 321 Steam 321 314 18 19 22 21 125 130 Consolidation adjustments — — (24 ) (24) — — — — Total CECONY $3,039 $2,884 $— $— $334 $310 $726 $705 O&R Electric $145 $149 $— $— $15 $14 $16 $8 Gas 113 97 — — 6 5 38 36 Total O&R $258 $246 $— $— $21 $19 $54 $44 Clean Energy Businesses $217 $233 $— $— $58 $19 $11 $9 Con Edison Transmission 1 1 — — — — (2) (1) Other (a) (1) — — — — — (3) (2) Total Con Edison $3,514 $3,364 $— $— $413 $348 $786 $755 (a) Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the consolidated balance sheet at fair value (see Note M), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules. In August 2017, the FASB issued amendments to the guidance for derivatives and hedging through ASU 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities.” The amendments in this update provide greater clarification on hedge accounting for risk components, presentation and disclosure of hedging instruments, and overall targeted improvements to simplify hedge accounting. The amendment was effective for reporting periods beginning after December 15, 2018. The application of the guidance did not have a material impact on the Companies’ financial position, results of operations and liquidity because the Companies do not elect hedge accounting for their derivative instruments and hedging activities. The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at March 31, 2019 and December 31, 2018 were: (Millions of Dollars) 2019 2018 Balance Sheet Location Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Con Edison Fair value of derivative assets Current $72 $(37) $35 (b) $43 $(14) $29 (b) Noncurrent 6 (5) 1 (c) 14 (7) 7 (d) Total fair value of derivative assets $78 $(42) $36 $57 $(21) $36 Fair value of derivative liabilities Current $(78) $32 $(46) $(61) $11 $(50) Noncurrent (44) 7 (37) (c) (19) 9 (10) (d) Total fair value of derivative liabilities $(122) $39 $(83) $(80) $20 $(60) Net fair value derivative assets/(liabilities) $(44) $(3) $(47) $(23) $(1) $(24) CECONY Fair value of derivative assets Current $62 $(31) $31 (b) $25 $(6) $19 (b) Noncurrent 4 (4) — 11 (5) 6 Total fair value of derivative assets $66 $(35) $31 $36 $(11) $25 Fair value of derivative liabilities Current $(53) $29 $(24) $(31) $6 $(25) Noncurrent (37) 5 (32) (12) 6 (6) Total fair value of derivative liabilities $(90) $34 $(56) $(43) $12 $(31) Net fair value derivative assets/(liabilities) $(24) $(1) $(25) $(7) $1 $(6) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At March 31, 2019 and December 31, 2018 , margin deposits for Con Edison ( $4 million and $7 million , respectively) and CECONY ( $4 million and $6 million , respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Does not include interest rate swaps of $1 million in noncurrent assets and $(14) million in noncurrent liabilities (see below). (d) Does not include interest rate swaps of $2 million in noncurrent assets and $(6) million in noncurrent liabilities (see below). The Utilities generally recover 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 regulators. 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. The Clean Energy Businesses record realized and unrealized gains and losses on their derivative contracts in purchased power, gas purchased for resale and non-utility revenue in the reporting period in which they occur. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices. The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the three months ended March 31, 2019 and 2018 : For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2019 2018 2019 2018 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $5 $(22) $3 $(22) Noncurrent Deferred derivative gains (6) (2) (5) (1) Total deferred gains/(losses) $(1) $(24) $(2) $(23) Current Deferred derivative losses $(3) $(48) $— $(44) Current Recoverable energy costs (18) 25 (14) 25 Noncurrent Deferred derivative losses (26) (51) (26) (49) Total deferred gains/(losses) $(47) $(74) $(40) $(68) Net deferred gains/(losses) $(48) $(98) $(42) $(91) Income Statement Location Pre-tax gains/(losses) recognized in income Purchased power expense $— $— $— $— Gas purchased for resale (3) — — — Non-utility revenue 9 (a) 4 (b) — — Total pre-tax gains/(losses) recognized in income $6 $4 $— $— (a) For the three months ended March 31, 2019 , Con Edison recorded unrealized pre-tax losses in non-utility operating revenue ( $1 million ). (b) For the three months ended March 31, 2018 , Con Edison recorded an immaterial unrealized pre-tax gain in non-utility operating revenue. The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at March 31, 2019 : Electric Energy (MWh) (a)(b) Capacity (MW) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 26,349,795 21,573 140,301,096 8,736,000 CECONY 24,284,875 10,200 130,060,000 8,736,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts, which are associated with electric and gas contracts and hedged volumes. 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 Clean Energy Businesses. Credit risk relates to the loss that may result from a counterparty’s nonperformance. The Companies use credit policies to manage this risk, including an established credit approval process, monitoring of counterparty limits, netting provisions within agreements, collateral or prepayment arrangements, credit insurance and credit default swaps. The Companies measure credit risk exposure as the replacement cost for open energy commodity and derivative positions plus amounts owed from counterparties for settled transactions. The replacement cost of open positions represents unrealized gains, net of any unrealized losses where the Companies have a legally enforceable right to offset. At March 31, 2019 , Con Edison and CECONY had $115 million and $11 million of credit exposure in connection with open energy supply net receivables and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $38 million with investment-grade counterparties, $32 million with independent system operators, $32 million with non-investment grade/non-rated counterparties and $13 million with commodity exchange brokers. CECONY’s net credit exposure consisted of $6 million with commodity exchange brokers and $5 million with investment-grade counterparties. 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 a party to provide collateral on its derivative instruments that are in a net liability position. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the party’s credit ratings. The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions 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 at March 31, 2019 : (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $55 $42 Collateral posted 26 19 Additional collateral (b) (downgrade one level from current ratings) — — Additional collateral (b) (downgrade to below investment grade from current ratings) 44 (c) 28 (c) (a) Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $1 million at March 31, 2019 . For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity. (b) The Companies measure the collateral requirements by taking into consideration the fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability 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 to offset. (c) Derivative instruments that are net assets have been excluded from the table. At March 31, 2019 , if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $14 million . Interest Rate Swaps In December 2018, the Clean Energy Businesses acquired Sempra Solar Holdings, LLC, which holds interest rate swaps that terminate in 2025, 2028 and 2035. The fair value of these interest rate swaps were a net liability of $13 million and $5 million as of March 31, 2019 and December 31, 2018 , respectively, on Con Edison's consolidated balance sheet. In December 2016, the Clean Energy Businesses acquired Coram Wind, which holds an interest rate swap that terminates in June 2024, pursuant to which it pays a fixed-rate of 2.0855 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap was an immaterial amount and a net asset of $1 million as of March 31, 2019 and December 31, 2018 , respectively, on Con Edison’s consolidated balance sheet.

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The accounting rules for fair value measurements and disclosures define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. The accounting rules for fair value measurements and disclosures established a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows: • Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange. • Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models. • Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value. Assets and liabilities measured at fair value on a recurring basis as of March 31, 2019 and December 31, 2018 are summarized below. 2019 2018 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $5 $39 $2 $(6) $40 $6 $36 $7 $(6) $43 Interest rate swap (a)(b)(c)(f) — 1 — — 1 — 2 — — 2 Other (a)(b)(d) 307 117 — — 424 287 114 — — 401 Total assets $312 $157 $2 $(6) $465 $293 $152 $7 $(6) $446 Derivative liabilities: Commodity (a)(b)(c) $5 $63 $21 $(6) $83 $8 $43 $20 $(11) $60 Interest rate swap (a)(b)(c)(f) — 14 — — 14 — 6 — — 6 Total liabilities $5 $77 $21 $(6) $97 $8 $49 $20 $(11) $66 CECONY Derivative assets: Commodity (a)(b)(c) $3 $33 $1 $(2) $35 $3 $28 $1 $(1) $31 Other (a)(b)(d) 287 111 — — 398 267 109 — — 376 Total assets $290 $144 $1 $(2) $433 $270 $137 $1 $(1) $407 Derivative liabilities: Commodity (a)(b)(c) $2 $53 $6 $(4) $57 $5 $30 $3 $(6) $32 (a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. Con Edison and CECONY had no transfers between levels 1, 2, and 3 during the three months ended March 31, 2019. Con Edison and CECONY had $2 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2018 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of December 31, 2017 to less than three years as of December 31, 2018 . (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At March 31, 2019 and December 31, 2018 , the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) 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. (f) See Note L. The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives. Fair value and changes in fair value of commodity derivatives are reported on a monthly basis to the Companies’ risk committees, comprised of officers and employees of the Companies that oversee energy hedging at the Utilities and the Clean Energy Businesses. The risk management group reports to the Companies’ Vice President and Treasurer. Fair Value of Level 3 at March 31, 2019 Valuation Techniques Unobservable Inputs Range (Millions of Dollars) Con Edison – Commodity Electricity $(16) Discounted Cash Flow Forward energy prices (a) $20.11-$32.31 per MWh Discounted Cash Flow Forward capacity prices (a) $0.75-$4.85 per kW-month Natural Gas (4) Discounted Cash Flow Forward natural gas prices (a) $1.27-$2.81 per Dt Transmission Congestion Contracts/Financial Transmission Rights 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.04-$2.9 per MWh Total Con Edison—Commodity $(19) CECONY – Commodity Electricity $(6) Discounted Cash Flow Forward capacity prices (a) $0.75-$4.85 per kW-month Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.27-$2.90 per MWh Total CECONY—Commodity $(5) (a) Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement. (b) Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement. The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of March 31, 2019 and 2018 and classified as Level 3 in the fair value hierarchy: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Beginning balance as of January 1, $(13) $1 $(2) $4 Included in earnings (4) 2 — 2 Included in regulatory assets and liabilities (5) 2 (3) (1) Settlements 3 (1) — (2) Transfer out of level 3 — (1) — (1) Ending balance as of March 31, $(19) $3 $(5) $2 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 regulators. 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 Clean Energy Businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ( $1 million loss and $2 million gain) and purchased power costs (immaterial for both periods) on the consolidated income statement for the three months ended March 31, 2019 and 2018 , respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at March 31, 2019 and 2018 is included in non-utility revenues ( $1 million loss and $1 million gain) and purchased power costs (immaterial for both periods) on the consolidated income statement for the three months ended March 31, 2019 and 2018 , respectively.

Variable Interest Entities

Variable Interest Entities	3 Months Ended
	Mar. 31, 2019
Equity Method Investments and Joint Ventures [Abstract]
Variable Interest Entities	Variable Interest Entities The accounting rules for consolidation address the consolidation of a variable interest entity (VIE) by a business enterprise that is the primary beneficiary. A VIE is an entity that does not have a sufficient equity investment at risk to permit it to finance its activities without additional subordinated financial support, or whose equity investors lack the characteristics of a controlling financial interest. The primary beneficiary is the business enterprise that has the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and either absorbs a significant amount of the VIE’s losses or has the right to receive benefits that could be significant to the VIE. The Companies enter into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, the Companies retain or may retain a variable interest in these entities. CECONY CECONY has an ongoing long-term electricity purchase agreement with Brooklyn Navy Yard Cogeneration Partners, LP, a potential VIE. In 2018, a request was made of this counterparty for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. The payments for this contract constitute CECONY’s maximum exposure to loss with respect to the potential VIE. Con Edison Development Con Edison has a variable interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), which is a consolidated entity in which Con Edison Development has an 80 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by a Con Edison Development subsidiary. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project. Electricity generated by the project is sold pursuant to a long-term power purchase agreement. Con Edison's earnings from Texas Solar 4 for the three months ended March 31, 2019 and 2018 were immaterial. In December 2018, a Con Edison Development subsidiary completed its acquisition of Sempra Solar Holdings, LLC. Included in the acquisition were certain operating projects (Tax Equity Projects) with a noncontrolling tax equity investor to which a percentage of earnings, tax attributes and cash flows are allocated. The Tax Equity Projects are consolidated entities in which Con Edison has less than a 100 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of the Tax Equity Projects is held by Con Edison Development subsidiaries. Electricity generated by the Tax Equity Projects is sold to utilities and municipalities pursuant to long-term power purchase agreements. For the three months ended March 31, 2019 , the hypothetical liquidation at book value (HLBV) method of accounting for the Tax Equity Projects resulted in $21 million of income( $16 million , after-tax) for the tax equity investor and a $19 million loss ( $14 million , after-tax) for Con Edison. At March 31, 2019 and December 31, 2018 , Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs: Tax Equity Projects Great Valley Solar Copper Mountain - Mesquite Solar Texas Solar 4 (Millions of Dollars) 2019 2018 2019 2018 2019 2018 Restricted cash $— $— $— $— $6 $4 Non-utility property, less accumulated depreciation (g)(h) 311 313 492 492 95 98 Other assets 36 18 109 97 10 9 Total assets (a) $347 $331 $601 $589 $111 $111 Long-term debt due within one year $— $— $— $— $2 $2 Other liabilities 33 17 45 33 28 26 Long-term debt — — — — 56 56 Total liabilities (b) $33 $17 $45 $33 $86 $84 (a) The assets of the Tax Equity Projects and Texas Solar 4 represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE. (b) The liabilities of the Tax Equity Projects and Texas Solar 4 represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. (c) Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Great Valley Solar consists of the Great Valley Solar 1, Great Valley Solar 2, Great Valley Solar 3 and Great Valley Solar 4 projects, for which the noncontrolling interest of the tax equity investor was $39 million and $33 million at March 31, 2019 and December 31, 2018, respectively. (e) Copper Mountain - Mesquite Solar consists of the Copper Mountain Solar 4, Mesquite Solar 2 and Mesquite Solar 3 projects for which the noncontrolling interest of the tax equity investor was $83 million and $71 million at March 31, 2019 and December 31, 2018 , respectively. (f) Noncontrolling interest of the third party was $7 million at March 31, 2019 and December 31, 2018 . (g) Non-utility property is reduced by accumulated depreciation of $3 million for Great Valley Solar, $4 million for Copper Mountain - Mesquite Solar and $16 million for Texas Solar 4 at March 31, 2019. (h) Non-utility property is reduced by accumulated depreciation of $1 million for Great Valley Solar, $1 million for Copper Mountain - Mesquite Solar and $15 million for Texas Solar 4 at December 31, 2018.

New Financial Accounting Standa

New Financial Accounting Standards	3 Months Ended
	Mar. 31, 2019
Accounting Changes and Error Corrections [Abstract]
New Financial Accounting Standards	New Financial Accounting Standards In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity. In January 2017, the FASB issued amendments to the guidance for the subsequent measurement of goodwill through ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The amendments in this update simplify goodwill impairment testing by eliminating Step 2 of the goodwill impairment test wherein an entity has to compute the implied fair value of goodwill by performing procedures to determine the fair value of its assets and liabilities. Under the new guidance, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value up to the total amount of goodwill allocated to that reporting unit. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In August 2018, the FASB issued amendments to the guidance for internal use software through ASU 2018-15, “Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract.” The amendments align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019, with early adoption permitted. The Companies elected to adopt the amendments in 2018, prospectively for all in-scope implementation costs incurred after the date of adoption. The impact of adoption on the Companies’ financial position, results of operations and liquidity was immaterial.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies and Other Matters (Policies)	3 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
New Financial Accounting Standards	New Financial Accounting Standards In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity. In January 2017, the FASB issued amendments to the guidance for the subsequent measurement of goodwill through ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The amendments in this update simplify goodwill impairment testing by eliminating Step 2 of the goodwill impairment test wherein an entity has to compute the implied fair value of goodwill by performing procedures to determine the fair value of its assets and liabilities. Under the new guidance, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value up to the total amount of goodwill allocated to that reporting unit. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. In August 2018, the FASB issued amendments to the guidance for internal use software through ASU 2018-15, “Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract.” The amendments align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019, with early adoption permitted. The Companies elected to adopt the amendments in 2018, prospectively for all in-scope implementation costs incurred after the date of adoption. The impact of adoption on the Companies’ financial position, results of operations and liquidity was immaterial.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies and Other Matters (Tables)	3 Months Ended
	Mar. 31, 2019
Accounting Policies [Abstract]
Disaggregation of Revenue	The following table presents, for the three months ended March 31, 2019 , and 2018 revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source. For the Three Months Ended March 31, 2019 For the Three Months Ended March 31, 2018 (Millions of Dollars) Revenues from contracts with customers Other revenues (a) Total operating revenues Revenues from contracts with customers Other revenues (a) Total operating revenues CECONY Electric $1,714 $83 $1,797 $1,771 $(42) $1,729 Gas 910 11 921 835 6 841 Steam 317 4 321 315 (1) 314 Total CECONY $2,941 $98 $3,039 $2,921 $(37) $2,884 O&R Electric 143 2 145 152 (3) 149 Gas 114 (1) 113 110 (13) 97 Total O&R $257 $1 $258 $262 $(16) $246 Clean Energy Businesses Renewables 106 (b) — 106 132 (b) — 132 Energy services 23 — 23 17 — 17 Other — 88 88 — 84 84 Total Clean Energy Businesses $129 $88 $217 $149 $84 $233 Con Edison Transmission 1 — 1 1 — 1 Other (c) — (1) (1) — — — Total Con Edison $3,328 $186 $3,514 $3,333 $31 $3,364 (a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans. For the Clean Energy Businesses, this includes revenue from wholesale services. (b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $2 million and $89 million for the three months ended March 31, 2019 and 2018 , respectively, of revenue related to engineering, procurement and construction services. (c) P arent company and consolidation adjustments.
Change in Unbilled Contract and Unearned Revenues	2019 2018 (Millions of Dollars) Unbilled contract revenue (a) Unearned revenue (b) Unbilled contract revenue (a) Unearned revenue (b) Beginning balance as of January 1, $29 $20 $58 $87 Additions (c) 24 — 36 32 Subtractions (c) 15 1 (d) 15 70 (d) Ending balance as of March 31, $38 $19 $79 $49 (a) Unbilled contract revenue represents accumulated incurred costs and earned profits on contracts (revenue arrangements), which have been recorded as revenue, but have not yet been billed to customers, and which represent contract assets as defined in Topic 606. Substantially all accrued unbilled contract revenue is expected to be collected within one year. Unbilled contract revenue arises from the cost-to-cost method of revenue recognition. Unbilled contract revenue from fixed-price type contracts is converted to billed receivables when amounts are invoiced to customers according to contractual billing terms, which generally occur when deliveries or other performance milestones are completed. (b) Unearned revenue represents a liability for billings to customers in excess of earned revenue, which are contract liabilities as defined in Topic 606. (c) Additions for unbilled contract revenue and subtractions for unearned revenue represent additional revenue earned. Additions for unearned revenue and subtractions for unbilled contract revenue represent billings. Activity also includes appropriate balance sheet classification for the period. (d) Of the subtractions from unearned revenue, $1 million and $48 million were included in the balance as of January 1, 2019 and 2018, respectively.
Basic and Diluted Earnings Per Share	For the three months ended March 31, 2019 and 2018 , basic and diluted EPS for Con Edison are calculated as follows: For the Three Months Ended March 31, (Millions of Dollars, except per share amounts/Shares in Millions) 2019 2018 Net income for common stock $424 $428 Weighted average common shares outstanding – basic 322.5 310.4 Add: Incremental shares attributable to effect of potentially dilutive securities 0.9 1.2 Adjusted weighted average common shares outstanding – diluted 323.4 311.6 Net Income per common share – basic $1.31 $1.38 Net Income per common share – diluted $1.31 $1.37
Changes in Accumulated Other Comprehensive Income/(Loss)	For the three months ended March 31, 2019 and 2018 , changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Beginning balance, accumulated OCI, net of taxes (a) $(16) $(26) $(5) $(6) OCI before reclassifications, net of tax of $(1) for Con Edison in 2019 and 2018 2 3 — — Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2018 (a)(b) 2 1 — — Current period OCI, net of taxes 4 4 — — Ending balance, accumulated OCI, net of taxes $(12) $(22) $(5) $(6) (a) Tax reclassified from accumulated OCI is reported in the income tax expense line item of the consolidated income statement. (b) For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of total periodic pension and other postretirement benefit cost. See Notes E and F.
Restrictions on Cash and Cash Equivalents	At March 31, 2019 and 2018 , cash, temporary cash investments and restricted cash for Con Edison and CECONY are as follows: At March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Cash and temporary cash investments $406 $651 $352 $574 Restricted cash (a) 68 32 — — Total cash, temporary cash investments and restricted cash $474 $683 $352 $574 (a) Restricted cash included cash of Con Edison Development renewable electric production project subsidiaries ( $67 million and $31 million at March 31, 2019 and 2018 , respectively) that, under the related project debt agreements, is restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves. During the pendency of the PG&E bankruptcy, unless the lenders for the related project debt otherwise agree, cash may not be distributed from the related projects to Con Edison Development. See “Long-Lived and Intangible Assets,” above, and Note C. In addition, restricted cash includes O&R's New Jersey utility subsidiary, Rockland Electric Company transition bond charge collections, net of principal, interest, trustee and service fees ( $1 million at March 31, 2019 and 2018 ) that are restricted until the bonds mature in 2019 .
Schedule of Cash and Cash Equivalents	At March 31, 2019 and 2018 , cash, temporary cash investments and restricted cash for Con Edison and CECONY are as follows: At March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Cash and temporary cash investments $406 $651 $352 $574 Restricted cash (a) 68 32 — — Total cash, temporary cash investments and restricted cash $474 $683 $352 $574 (a) Restricted cash included cash of Con Edison Development renewable electric production project subsidiaries ( $67 million and $31 million at March 31, 2019 and 2018 , respectively) that, under the related project debt agreements, is restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves. During the pendency of the PG&E bankruptcy, unless the lenders for the related project debt otherwise agree, cash may not be distributed from the related projects to Con Edison Development. See “Long-Lived and Intangible Assets,” above, and Note C. In addition, restricted cash includes O&R's New Jersey utility subsidiary, Rockland Electric Company transition bond charge collections, net of principal, interest, trustee and service fees ( $1 million at March 31, 2019 and 2018 ) that are restricted until the bonds mature in 2019 .

Regulatory Matters (Tables)

Regulatory Matters (Tables)	3 Months Ended
	Mar. 31, 2019
Regulated Operations [Abstract]
Schedule of Regulatory Assets	Regulatory assets and liabilities at March 31, 2019 and December 31, 2018 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Regulatory assets Unrecognized pension and other postretirement costs $2,166 $2,238 $2,052 $2,111 Environmental remediation costs 798 810 706 716 Revenue taxes 299 291 286 278 MTA power reliability deferral 239 229 239 229 Property tax reconciliation 114 101 101 86 Deferred storm costs 77 76 — — Municipal infrastructure support costs 75 67 75 67 Pension and other postretirement benefits deferrals 63 73 45 56 System peak reduction and energy efficiency programs 60 72 59 70 Deferred derivative losses 43 17 37 11 Brooklyn Queens demand management program 37 39 37 39 Meadowlands heater odorization project 36 36 36 36 Unamortized loss on reacquired debt 34 36 32 34 Preferred stock redemption 23 23 23 23 Recoverable REV demonstration project costs 20 20 18 18 Gate station upgrade project 18 17 18 17 Indian Point Energy Center program costs 7 13 7 13 Workers’ compensation 6 5 6 5 O&R transition bond charges 1 2 — — Other 129 129 118 114 Regulatory assets – noncurrent 4,245 4,294 3,895 3,923 Deferred derivative losses 39 36 29 29 Recoverable energy costs 4 40 — 35 Regulatory assets – current 43 76 29 64 Total Regulatory Assets $4,288 $4,370 $3,924 $3,987 Regulatory liabilities Future income tax $2,496 $2,515 $2,347 $2,363 Allowance for cost of removal less salvage 934 928 795 790 TCJA net benefits* 438 434 417 411 Energy efficiency portfolio standard unencumbered funds 124 127 119 122 Net unbilled revenue deferrals 115 117 115 117 Pension and other postretirement benefit deferrals 62 62 38 40 Net proceeds from sale of property 46 6 46 6 Property tax refunds 45 45 45 45 System benefit charge carrying charge 31 27 28 24 Settlement of prudence proceeding 29 37 29 37 Property tax reconciliation 26 36 26 36 BQDM and REV Demo reconciliations 20 18 20 18 Earnings sharing - electric, gas and steam 19 36 10 27 Carrying charges on repair allowance and bonus depreciation 15 21 14 21 Settlement of gas proceedings 15 15 15 15 New York State income tax rate change 12 17 12 17 Unrecognized other postretirement costs 11 7 6 7 Base rate change deferrals 7 10 7 10 Other 168 183 131 152 Regulatory liabilities – noncurrent 4,613 4,641 4,220 4,258 Revenue decoupling mechanism 34 53 22 36 Refundable energy costs 83 31 51 8 Deferred derivative gains 35 30 32 29 Regulatory liabilities – current 152 114 105 73 Total Regulatory Liabilities $4,765 $4,755 $4,325 $4,331 * See "Other Regulatory Matters," above.
Schedule of Regulatory Liabilities	Regulatory assets and liabilities at March 31, 2019 and December 31, 2018 were comprised of the following items: Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Regulatory assets Unrecognized pension and other postretirement costs $2,166 $2,238 $2,052 $2,111 Environmental remediation costs 798 810 706 716 Revenue taxes 299 291 286 278 MTA power reliability deferral 239 229 239 229 Property tax reconciliation 114 101 101 86 Deferred storm costs 77 76 — — Municipal infrastructure support costs 75 67 75 67 Pension and other postretirement benefits deferrals 63 73 45 56 System peak reduction and energy efficiency programs 60 72 59 70 Deferred derivative losses 43 17 37 11 Brooklyn Queens demand management program 37 39 37 39 Meadowlands heater odorization project 36 36 36 36 Unamortized loss on reacquired debt 34 36 32 34 Preferred stock redemption 23 23 23 23 Recoverable REV demonstration project costs 20 20 18 18 Gate station upgrade project 18 17 18 17 Indian Point Energy Center program costs 7 13 7 13 Workers’ compensation 6 5 6 5 O&R transition bond charges 1 2 — — Other 129 129 118 114 Regulatory assets – noncurrent 4,245 4,294 3,895 3,923 Deferred derivative losses 39 36 29 29 Recoverable energy costs 4 40 — 35 Regulatory assets – current 43 76 29 64 Total Regulatory Assets $4,288 $4,370 $3,924 $3,987 Regulatory liabilities Future income tax $2,496 $2,515 $2,347 $2,363 Allowance for cost of removal less salvage 934 928 795 790 TCJA net benefits* 438 434 417 411 Energy efficiency portfolio standard unencumbered funds 124 127 119 122 Net unbilled revenue deferrals 115 117 115 117 Pension and other postretirement benefit deferrals 62 62 38 40 Net proceeds from sale of property 46 6 46 6 Property tax refunds 45 45 45 45 System benefit charge carrying charge 31 27 28 24 Settlement of prudence proceeding 29 37 29 37 Property tax reconciliation 26 36 26 36 BQDM and REV Demo reconciliations 20 18 20 18 Earnings sharing - electric, gas and steam 19 36 10 27 Carrying charges on repair allowance and bonus depreciation 15 21 14 21 Settlement of gas proceedings 15 15 15 15 New York State income tax rate change 12 17 12 17 Unrecognized other postretirement costs 11 7 6 7 Base rate change deferrals 7 10 7 10 Other 168 183 131 152 Regulatory liabilities – noncurrent 4,613 4,641 4,220 4,258 Revenue decoupling mechanism 34 53 22 36 Refundable energy costs 83 31 51 8 Deferred derivative gains 35 30 32 29 Regulatory liabilities – current 152 114 105 73 Total Regulatory Liabilities $4,765 $4,755 $4,325 $4,331 * See "Other Regulatory Matters," above.

Capitalization (Tables)

Capitalization (Tables)	3 Months Ended
	Mar. 31, 2019
Debt Disclosure [Abstract]
Carrying Amounts and Fair Values of Long-Term Debt	The carrying amounts and fair values of long-term debt at March 31, 2019 and December 31, 2018 were: (Millions of Dollars) 2019 2018 Long-Term Debt (including current portion) (a) Carrying Amount Fair Value Carrying Amount Fair Value Con Edison $18,962 $20,304 $18,145 $18,740 CECONY $14,153 $15,371 $14,151 $14,685 (a) Amounts shown are net of unamortized debt expense and unamortized debt discount of $181 million and $137 million for Con Edison and CECONY, respectively, as of March 31, 2019 and $185 million and $139 million for Con Edison and CECONY, respectively, as of December 31, 2018 .

Pension Benefits (Tables)

Pension Benefits (Tables)	3 Months Ended
	Mar. 31, 2019
Retirement Benefits [Abstract]
Total Periodic Benefit Costs	The components of the Companies’ total periodic benefit cost for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Service cost – including administrative expenses $62 $72 $58 $68 Interest cost on projected benefit obligation 150 140 141 131 Expected return on plan assets (247) (258) (234) (245) Recognition of net actuarial loss 130 172 123 163 Recognition of prior service cost/(credit) (4) (4) (5) (5) TOTAL PERIODIC BENEFIT COST $91 $122 $83 $112 Cost capitalized (26) (31) (24) (29) Reconciliation to rate level (5) (23) (4) (25) Total expense recognized $60 $68 $55 $58 The components of the Companies’ total periodic other postretirement benefit cost/(credit) for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Service cost $4 $5 $3 $3 Interest cost on accumulated other postretirement benefit obligation 11 11 9 9 Expected return on plan assets (16) (18) (14) (16) Recognition of net actuarial loss/(gain) (2) 2 (2) 1 Recognition of prior service cost/(credit) (1) (2) — (1) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT) $(4) $(2) $(4) $(4) Cost capitalized (2) (2) (2) (2) Reconciliation to rate level 3 2 2 3 Total expense/(credit) recognized $(3) $(2) $(4) $(3)

Other Postretirement Benefits (

Other Postretirement Benefits (Tables)	3 Months Ended
	Mar. 31, 2019
Retirement Benefits [Abstract]
Total Periodic Benefit Costs	The components of the Companies’ total periodic benefit cost for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Service cost – including administrative expenses $62 $72 $58 $68 Interest cost on projected benefit obligation 150 140 141 131 Expected return on plan assets (247) (258) (234) (245) Recognition of net actuarial loss 130 172 123 163 Recognition of prior service cost/(credit) (4) (4) (5) (5) TOTAL PERIODIC BENEFIT COST $91 $122 $83 $112 Cost capitalized (26) (31) (24) (29) Reconciliation to rate level (5) (23) (4) (25) Total expense recognized $60 $68 $55 $58 The components of the Companies’ total periodic other postretirement benefit cost/(credit) for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Service cost $4 $5 $3 $3 Interest cost on accumulated other postretirement benefit obligation 11 11 9 9 Expected return on plan assets (16) (18) (14) (16) Recognition of net actuarial loss/(gain) (2) 2 (2) 1 Recognition of prior service cost/(credit) (1) (2) — (1) TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT) $(4) $(2) $(4) $(4) Cost capitalized (2) (2) (2) (2) Reconciliation to rate level 3 2 2 3 Total expense/(credit) recognized $(3) $(2) $(4) $(3)

Environmental Matters (Tables)

Environmental Matters (Tables)	3 Months Ended
	Mar. 31, 2019
Environmental Remediation Obligations [Abstract]
Accrued Liabilities and Regulatory Assets	The accrued liabilities and regulatory assets related to Superfund Sites at March 31, 2019 and December 31, 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Accrued Liabilities: Manufactured gas plant sites $687 $689 $602 $603 Other Superfund Sites 89 90 89 90 Total $776 $779 $691 $693 Regulatory assets $798 $810 $706 $716
Environmental Remediation Costs	Environmental remediation costs incurred related to Superfund Sites for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Remediation costs incurred $3 $3 $2 $3
Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings	The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at March 31, 2019 and December 31, 2018 were as follows: Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Accrued liability – asbestos suits $8 $8 $7 $7 Regulatory assets – asbestos suits $8 $8 $7 $7 Accrued liability – workers’ compensation $80 $79 $76 $75 Regulatory assets – workers’ compensation $6 $5 $6 $5

Other Material Contingencies (T

Other Material Contingencies (Tables)	3 Months Ended
	Mar. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Summary of Total Guarantees	A summary, by type and term, of Con Edison’s total guarantees under these agreements at March 31, 2019 is as follows: Guarantee Type 0 – 3 years 4 – 10 years > 10 years Total (Millions of Dollars) Con Edison Transmission $539 $337 $— $876 Energy transactions 490 19 200 709 Renewable electric production projects 142 — 402 544 Other 70 — — 70 Total $1,241 $356 $602 $2,199

Leases (Tables)

Leases (Tables)	3 Months Ended
	Mar. 31, 2019
Leases [Abstract]
Lease Costs, Cash Flows and Other Related Information	Con Edison CECONY Weighted Average Remaining Lease Term: Operating leases 19.3 years 14.7 years Finance leases 10.0 years 2.5 years Weighted Average Discount Rate: Operating leases 4.3% 3.6% Finance leases 4.2% 5.3% Operating lease cost and cash paid for amounts included in the measurement of lease liabilities were as follows for Con Edison and CECONY for the three months ended March 31, 2019 : (Millions of Dollars) Con Edison CECONY Operating lease cost $21 $16 Operating lease cash flows $8 $4
Operating Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at March 31, 2019 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending March 31, Operating Leases Finance Leases Operating Leases Finance Leases 2020 $79 $1 $58 $1 2021 74 — 58 — 2022 71 — 55 — 2023 69 — 53 — 2024 68 — 53 — All years thereafter 973 1 553 — Total future minimum lease payments $1,334 $2 $830 $1 Less: imputed interest (459) — (191) — Total $875 $2 $639 $1 Reported as of March 31, 2019 Operating lease liabilities (current) $50 $— $41 $— Operating lease liabilities (noncurrent) 825 — 598 — Other current liabilities — 1 — 1 Other noncurrent liabilities — 1 — — Total $875 $2 $639 $1
Finance Leases, Future Minimum Lease Payments	Future minimum lease payments under non-cancellable leases at March 31, 2019 were as follows: (Millions of Dollars) Con Edison CECONY Year Ending March 31, Operating Leases Finance Leases Operating Leases Finance Leases 2020 $79 $1 $58 $1 2021 74 — 58 — 2022 71 — 55 — 2023 69 — 53 — 2024 68 — 53 — All years thereafter 973 1 553 — Total future minimum lease payments $1,334 $2 $830 $1 Less: imputed interest (459) — (191) — Total $875 $2 $639 $1 Reported as of March 31, 2019 Operating lease liabilities (current) $50 $— $41 $— Operating lease liabilities (noncurrent) 825 — 598 — Other current liabilities — 1 — 1 Other noncurrent liabilities — 1 — — Total $875 $2 $639 $1
Future Minimum Lease Commitments Accounted for Under Topic 840	The future minimum lease commitments at December 31, 2018, accounted for under Topic 840, for the Companies’ operating lease agreements that are not cancellable by the Companies were as follows: (Millions of Dollars) Con Edison CECONY 2019 $72 $56 2020 72 56 2021 71 54 2022 68 53 2023 68 53 All years thereafter 890 592 Total $1,241 $864

Income Tax (Tables)

Income Tax (Tables)	3 Months Ended
	Mar. 31, 2019
Income Tax Disclosure [Abstract]
Schedule of Income Tax Reconciliation	Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes for the three months ended March 31, is as follows: Con Edison CECONY (% of Pre-tax income) 2019 2018 2019 2018 STATUTORY TAX RATE Federal 21 % 21 % 21 % 21 % Changes in computed taxes resulting from: State income tax 5 4 6 5 Cost of removal 1 1 1 1 Other plant-related items (1 ) — — (1 ) Renewable energy credits (1 ) (1 ) — — Amortization of excess deferred federal income taxes (4 ) (3 ) (4 ) (3 ) Other (1 ) (1 ) (1 ) — Effective tax rate 20 % 21 % 23 % 23 %

Financial Information by Busi_2

Financial Information by Business Segment (Tables)	3 Months Ended
	Mar. 31, 2019
Segment Reporting [Abstract]
Financial Data for Business Segments	The financial data for the business segments for the three months ended March 31, 2019 and 2018 were as follows: For the Three Months Ended March 31, Operating revenues Inter-segment revenues Depreciation and amortization Operating income/(loss) (Millions of Dollars) 2019 2018 2019 2018 2019 2018 2019 2018 CECONY Electric $1,797 $1,729 $4 $4 $257 $240 $257 $254 Gas 921 841 2 1 55 49 344 321 Steam 321 314 18 19 22 21 125 130 Consolidation adjustments — — (24 ) (24) — — — — Total CECONY $3,039 $2,884 $— $— $334 $310 $726 $705 O&R Electric $145 $149 $— $— $15 $14 $16 $8 Gas 113 97 — — 6 5 38 36 Total O&R $258 $246 $— $— $21 $19 $54 $44 Clean Energy Businesses $217 $233 $— $— $58 $19 $11 $9 Con Edison Transmission 1 1 — — — — (2) (1) Other (a) (1) — — — — — (3) (2) Total Con Edison $3,514 $3,364 $— $— $413 $348 $786 $755 (a) Parent company and consolidation adjustments. Other does not represent a business segment.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Offsetting of Liabilities	The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at March 31, 2019 and December 31, 2018 were: (Millions of Dollars) 2019 2018 Balance Sheet Location Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Con Edison Fair value of derivative assets Current $72 $(37) $35 (b) $43 $(14) $29 (b) Noncurrent 6 (5) 1 (c) 14 (7) 7 (d) Total fair value of derivative assets $78 $(42) $36 $57 $(21) $36 Fair value of derivative liabilities Current $(78) $32 $(46) $(61) $11 $(50) Noncurrent (44) 7 (37) (c) (19) 9 (10) (d) Total fair value of derivative liabilities $(122) $39 $(83) $(80) $20 $(60) Net fair value derivative assets/(liabilities) $(44) $(3) $(47) $(23) $(1) $(24) CECONY Fair value of derivative assets Current $62 $(31) $31 (b) $25 $(6) $19 (b) Noncurrent 4 (4) — 11 (5) 6 Total fair value of derivative assets $66 $(35) $31 $36 $(11) $25 Fair value of derivative liabilities Current $(53) $29 $(24) $(31) $6 $(25) Noncurrent (37) 5 (32) (12) 6 (6) Total fair value of derivative liabilities $(90) $34 $(56) $(43) $12 $(31) Net fair value derivative assets/(liabilities) $(24) $(1) $(25) $(7) $1 $(6) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At March 31, 2019 and December 31, 2018 , margin deposits for Con Edison ( $4 million and $7 million , respectively) and CECONY ( $4 million and $6 million , respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Does not include interest rate swaps of $1 million in noncurrent assets and $(14) million in noncurrent liabilities (see below). (d) Does not include interest rate swaps of $2 million in noncurrent assets and $(6) million in noncurrent liabilities (see below).
Offsetting of Assets	The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at March 31, 2019 and December 31, 2018 were: (Millions of Dollars) 2019 2018 Balance Sheet Location Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Gross Amounts of Recognized Assets/(Liabilities) Gross Amounts Offset Net Amounts of Assets/ (Liabilities) (a) Con Edison Fair value of derivative assets Current $72 $(37) $35 (b) $43 $(14) $29 (b) Noncurrent 6 (5) 1 (c) 14 (7) 7 (d) Total fair value of derivative assets $78 $(42) $36 $57 $(21) $36 Fair value of derivative liabilities Current $(78) $32 $(46) $(61) $11 $(50) Noncurrent (44) 7 (37) (c) (19) 9 (10) (d) Total fair value of derivative liabilities $(122) $39 $(83) $(80) $20 $(60) Net fair value derivative assets/(liabilities) $(44) $(3) $(47) $(23) $(1) $(24) CECONY Fair value of derivative assets Current $62 $(31) $31 (b) $25 $(6) $19 (b) Noncurrent 4 (4) — 11 (5) 6 Total fair value of derivative assets $66 $(35) $31 $36 $(11) $25 Fair value of derivative liabilities Current $(53) $29 $(24) $(31) $6 $(25) Noncurrent (37) 5 (32) (12) 6 (6) Total fair value of derivative liabilities $(90) $34 $(56) $(43) $12 $(31) Net fair value derivative assets/(liabilities) $(24) $(1) $(25) $(7) $1 $(6) (a) Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount. (b) At March 31, 2019 and December 31, 2018 , margin deposits for Con Edison ( $4 million and $7 million , respectively) and CECONY ( $4 million and $6 million , respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange. (c) Does not include interest rate swaps of $1 million in noncurrent assets and $(14) million in noncurrent liabilities (see below). (d) Does not include interest rate swaps of $2 million in noncurrent assets and $(6) million in noncurrent liabilities (see below).
Realized and Unrealized Gains or Losses on Commodity Derivatives	The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the three months ended March 31, 2019 and 2018 : For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) Balance Sheet Location 2019 2018 2019 2018 Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations: Current Deferred derivative gains $5 $(22) $3 $(22) Noncurrent Deferred derivative gains (6) (2) (5) (1) Total deferred gains/(losses) $(1) $(24) $(2) $(23) Current Deferred derivative losses $(3) $(48) $— $(44) Current Recoverable energy costs (18) 25 (14) 25 Noncurrent Deferred derivative losses (26) (51) (26) (49) Total deferred gains/(losses) $(47) $(74) $(40) $(68) Net deferred gains/(losses) $(48) $(98) $(42) $(91) Income Statement Location Pre-tax gains/(losses) recognized in income Purchased power expense $— $— $— $— Gas purchased for resale (3) — — — Non-utility revenue 9 (a) 4 (b) — — Total pre-tax gains/(losses) recognized in income $6 $4 $— $— (a) For the three months ended March 31, 2019 , Con Edison recorded unrealized pre-tax losses in non-utility operating revenue ( $1 million ). (b) For the three months ended March 31, 2018 , Con Edison recorded an immaterial unrealized pre-tax gain in non-utility operating revenue.
Hedged Volume of Derivative Transactions	The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at March 31, 2019 : Electric Energy (MWh) (a)(b) Capacity (MW) (a) Natural Gas (Dt) (a)(b) Refined Fuels (gallons) Con Edison 26,349,795 21,573 140,301,096 8,736,000 CECONY 24,284,875 10,200 130,060,000 8,736,000 (a) Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported. (b) Excludes electric congestion and gas basis swap contracts, which are associated with electric and gas contracts and hedged volumes.
Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features	The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions 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 at March 31, 2019 : (Millions of Dollars) Con Edison (a) CECONY (a) Aggregate fair value – net liabilities $55 $42 Collateral posted 26 19 Additional collateral (b) (downgrade one level from current ratings) — — Additional collateral (b) (downgrade to below investment grade from current ratings) 44 (c) 28 (c) (a) Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $1 million at March 31, 2019 . For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity. (b) The Companies measure the collateral requirements by taking into consideration the fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability 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 to offset. (c) Derivative instruments that are net assets have been excluded from the table. At March 31, 2019 , if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $14 million .

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value on Recurring Basis	Assets and liabilities measured at fair value on a recurring basis as of March 31, 2019 and December 31, 2018 are summarized below. 2019 2018 (Millions of Dollars) Level 1 Level 2 Level 3 Netting Adjustment (e) Total Level 1 Level 2 Level 3 Netting Adjustment (e) Total Con Edison Derivative assets: Commodity (a)(b)(c) $5 $39 $2 $(6) $40 $6 $36 $7 $(6) $43 Interest rate swap (a)(b)(c)(f) — 1 — — 1 — 2 — — 2 Other (a)(b)(d) 307 117 — — 424 287 114 — — 401 Total assets $312 $157 $2 $(6) $465 $293 $152 $7 $(6) $446 Derivative liabilities: Commodity (a)(b)(c) $5 $63 $21 $(6) $83 $8 $43 $20 $(11) $60 Interest rate swap (a)(b)(c)(f) — 14 — — 14 — 6 — — 6 Total liabilities $5 $77 $21 $(6) $97 $8 $49 $20 $(11) $66 CECONY Derivative assets: Commodity (a)(b)(c) $3 $33 $1 $(2) $35 $3 $28 $1 $(1) $31 Other (a)(b)(d) 287 111 — — 398 267 109 — — 376 Total assets $290 $144 $1 $(2) $433 $270 $137 $1 $(1) $407 Derivative liabilities: Commodity (a)(b)(c) $2 $53 $6 $(4) $57 $5 $30 $3 $(6) $32 (a) The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. Con Edison and CECONY had no transfers between levels 1, 2, and 3 during the three months ended March 31, 2019. Con Edison and CECONY had $2 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2018 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of December 31, 2017 to less than three years as of December 31, 2018 . (b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors. (c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At March 31, 2019 and December 31, 2018 , the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations. (d) Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans. (e) 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. (f) See Note L.
Schedule of Commodity Derivatives	Fair Value of Level 3 at March 31, 2019 Valuation Techniques Unobservable Inputs Range (Millions of Dollars) Con Edison – Commodity Electricity $(16) Discounted Cash Flow Forward energy prices (a) $20.11-$32.31 per MWh Discounted Cash Flow Forward capacity prices (a) $0.75-$4.85 per kW-month Natural Gas (4) Discounted Cash Flow Forward natural gas prices (a) $1.27-$2.81 per Dt Transmission Congestion Contracts/Financial Transmission Rights 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.04-$2.9 per MWh Total Con Edison—Commodity $(19) CECONY – Commodity Electricity $(6) Discounted Cash Flow Forward capacity prices (a) $0.75-$4.85 per kW-month Transmission Congestion Contracts 1 Discounted Cash Flow Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.27-$2.90 per MWh Total CECONY—Commodity $(5) (a) Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement. (b) Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement.
Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value	The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of March 31, 2019 and 2018 and classified as Level 3 in the fair value hierarchy: For the Three Months Ended March 31, Con Edison CECONY (Millions of Dollars) 2019 2018 2019 2018 Beginning balance as of January 1, $(13) $1 $(2) $4 Included in earnings (4) 2 — 2 Included in regulatory assets and liabilities (5) 2 (3) (1) Settlements 3 (1) — (2) Transfer out of level 3 — (1) — (1) Ending balance as of March 31, $(19) $3 $(5) $2

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	3 Months Ended
	Mar. 31, 2019
Equity Method Investments and Joint Ventures [Abstract]
Summary of VIEs	At March 31, 2019 and December 31, 2018 , Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs: Tax Equity Projects Great Valley Solar Copper Mountain - Mesquite Solar Texas Solar 4 (Millions of Dollars) 2019 2018 2019 2018 2019 2018 Restricted cash $— $— $— $— $6 $4 Non-utility property, less accumulated depreciation (g)(h) 311 313 492 492 95 98 Other assets 36 18 109 97 10 9 Total assets (a) $347 $331 $601 $589 $111 $111 Long-term debt due within one year $— $— $— $— $2 $2 Other liabilities 33 17 45 33 28 26 Long-term debt — — — — 56 56 Total liabilities (b) $33 $17 $45 $33 $86 $84 (a) The assets of the Tax Equity Projects and Texas Solar 4 represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE. (b) The liabilities of the Tax Equity Projects and Texas Solar 4 represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. (c) Con Edison did not provide any financial or other support during the year that was not previously contractually required. (d) Great Valley Solar consists of the Great Valley Solar 1, Great Valley Solar 2, Great Valley Solar 3 and Great Valley Solar 4 projects, for which the noncontrolling interest of the tax equity investor was $39 million and $33 million at March 31, 2019 and December 31, 2018, respectively. (e) Copper Mountain - Mesquite Solar consists of the Copper Mountain Solar 4, Mesquite Solar 2 and Mesquite Solar 3 projects for which the noncontrolling interest of the tax equity investor was $83 million and $71 million at March 31, 2019 and December 31, 2018 , respectively. (f) Noncontrolling interest of the third party was $7 million at March 31, 2019 and December 31, 2018 . (g) Non-utility property is reduced by accumulated depreciation of $3 million for Great Valley Solar, $4 million for Copper Mountain - Mesquite Solar and $16 million for Texas Solar 4 at March 31, 2019. (h) Non-utility property is reduced by accumulated depreciation of $1 million for Great Valley Solar, $1 million for Copper Mountain - Mesquite Solar and $15 million for Texas Solar 4 at December 31, 2018.

General (Details)

General (Details)	3 Months Ended
	Mar. 31, 2019subsidiaryregistrant
Accounting Policies [Abstract]
Number of registrants | registrant	2
Number of regulated utility subsidiaries	2
Clean Energy Businesses
Investment [Line Items]
Number of subsidiaries	3

Summary of Significant Accoun_4

Summary of Significant Accounting Policies and Other Matters - Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 3,328	$ 3,333
Total revenues	3,514	3,364
Other
Disaggregation of Revenue [Line Items]
Total revenues	186	31
Clean Energy Businesses | Renewables | Engineering, procurement and construction
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2	89
CECONY
Disaggregation of Revenue [Line Items]
Total revenues	3,039	2,884
Operating Segments
Disaggregation of Revenue [Line Items]
Total revenues	3,514	3,364
Operating Segments | Clean Energy Businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	129	149
Total revenues	217	233
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Total revenues	88	84
Operating Segments | Clean Energy Businesses | Renewables
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	106	132
Total revenues	106	132
Operating Segments | Clean Energy Businesses | Renewables | Other
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Operating Segments | Clean Energy Businesses | Energy services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	23	17
Total revenues	23	17
Operating Segments | Clean Energy Businesses | Energy services | Other
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0
Total revenues	88	84
Operating Segments | Clean Energy Businesses | Other | Other
Disaggregation of Revenue [Line Items]
Total revenues	88	84
Operating Segments | Con Edison Transmission
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	1
Total revenues	1	1
Operating Segments | Con Edison Transmission | Other
Disaggregation of Revenue [Line Items]
Total revenues	0	0
Operating Segments | CECONY
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,941	2,921
Total revenues	3,039	2,884
Operating Segments | CECONY | Other
Disaggregation of Revenue [Line Items]
Total revenues	98	(37)
Operating Segments | CECONY | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,714	1,771
Total revenues	1,797	1,729
Operating Segments | CECONY | Electric | Other
Disaggregation of Revenue [Line Items]
Total revenues	83	(42)
Operating Segments | CECONY | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	910	835
Total revenues	921	841
Operating Segments | CECONY | Gas | Other
Disaggregation of Revenue [Line Items]
Total revenues	11	6
Operating Segments | CECONY | Steam
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	317	315
Total revenues	321	314
Operating Segments | CECONY | Steam | Other
Disaggregation of Revenue [Line Items]
Total revenues	4	(1)
Operating Segments | O&R
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	257	262
Total revenues	258	246
Operating Segments | O&R | Other
Disaggregation of Revenue [Line Items]
Total revenues	1	(16)
Operating Segments | O&R | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	143	152
Total revenues	145	149
Operating Segments | O&R | Electric | Other
Disaggregation of Revenue [Line Items]
Total revenues	2	(3)
Operating Segments | O&R | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	114	110
Total revenues	113	97
Operating Segments | O&R | Gas | Other
Disaggregation of Revenue [Line Items]
Total revenues	$ (1)	$ (13)

Summary of Significant Accoun_5

Summary of Significant Accounting Policies and Other Matters - Change in Unbilled Contract and Unearned Revenues (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Jan. 01, 2019	Jan. 01, 2018
Unbilled contract revenue
Beginning balance	$ 29	$ 58
Additions	24	36
Subtractions	15	15
Ending balance	38	79
Unearned revenue
Beginning balance	20	87
Additions	0	32
Subtractions	1	70
Ending balance	$ 19	$ 49
Contracts with customer, revenue recognized, amount outstanding end of last period			$ 1	$ 48

Summary of Significant Accoun_6

Summary of Significant Accounting Policies and Other Matters - Revenue Recognition, Remaining Performance Obligation (Details) $ in Millions	Mar. 31, 2019USD ($)
Accounting Policies [Abstract]
Remaining performance obligation	$ 79
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Accounting Policies [Abstract]
Remaining performance obligation	$ 43
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing of satisfaction	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01
Accounting Policies [Abstract]
Remaining performance obligation	$ 36
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing of satisfaction

Summary of Significant Accoun_7

Summary of Significant Accounting Policies and Other Matters - Utility Plant (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Finite-Lived Intangible Assets [Line Items]
Accumulated amortization	$ 53	$ 29
Software Licenses
Finite-Lived Intangible Assets [Line Items]
Gross asset	98	100
Estimated aggregate annual amortization expense	7
Accumulated amortization	5	3
CECONY | Software Licenses
Finite-Lived Intangible Assets [Line Items]
Gross asset	93	95
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 5	$ 3

Summary of Significant Accoun_8

Summary of Significant Accounting Policies and Other Matters - Long-Lived and Intangible Assets (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)MW	Dec. 31, 2018USD ($)
Finite-Lived Intangible Assets [Line Items]
Net non-utility plant	$ 42,152	$ 41,749
Intangible assets	$ 1,630	1,654
PG&E Project
Finite-Lived Intangible Assets [Line Items]
Net non-utility plant		859
Intangible assets		1,108
Long-term debt		1,041
PG&E Project | Secured Related to Project Debt
Finite-Lived Intangible Assets [Line Items]
Net non-utility plant		$ 289
Con Edison Development | PG&E Project
Finite-Lived Intangible Assets [Line Items]
Aggregate power to be sold (in MW) | MW	680

Summary of Significant Accoun_9

Summary of Significant Accounting Policies and Other Matters - Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Accounting Policies [Abstract]
Net income for common stock	$ 424	$ 428
Weighted average common shares outstanding – basic (shares)	322.5	310.4
Add: Incremental shares attributable to effect of potentially dilutive securities (shares)	0.9	1.2
Adjusted weighted average common shares outstanding – diluted (shares)	323.4	311.6
Net income per common share - basic (dollars per share)	$ 1.31	$ 1.38
Net income per common share - diluted (dollars per share)	$ 1.31	$ 1.37

Summary of Significant Accou_10

Summary of Significant Accounting Policies and Other Matters - Changes in Accumulated Other Comprehensive Income/(Loss) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	$ 16,839	$ 15,425
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	4	4
Ending Balance	17,501	15,661
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(16)	(26)
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	4	4
Ending Balance	(12)	(22)
Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax of $(1) for Con Edison in 2019 and 2018	2	3
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2018	2	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	4	4
OCI before reclassifications, tax	(1)	(1)
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax		(1)
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	0	0
CECONY | Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(5)	(6)
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES
Ending Balance	(5)	(6)
CECONY | Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax of $(1) for Con Edison in 2019 and 2018	0	0
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2018	0	0
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	$ 0	$ 0

Summary of Significant Accou_11

Summary of Significant Accounting Policies and Other Matters - Reconciliation of Cash, Temporary Investments and Restricted Cash (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	$ 406	$ 895	$ 651
Restricted cash	68		32
Total cash, temporary cash investments and restricted cash	474	1,006	683	$ 844
CEB | Cash Collateral Held for Project Finance Agreements
Cash and Cash Equivalents [Line Items]
Restricted cash	67		31
CECONY
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	352	818	574
Restricted cash	0		0
Total cash, temporary cash investments and restricted cash	352	$ 818	574	$ 730
RECO | Transition Bond
Cash and Cash Equivalents [Line Items]
Restricted cash	$ 1		$ 1

Regulatory Matters - Rate Plans

Regulatory Matters - Rate Plans (Details) - NYSPSC - Scenario, Forecast - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate	$ (14)	$ 7	$ (12)
Requested rate increase (decrease), amount	249	359	473
CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Increase (decrease) in requested rate	(1)	(14)	(9)
Requested rate increase (decrease), amount	$ 154	124	201
O&R | Electric
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		5.8	8	$ 13.4
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ 0.7	$ 3.6	$ (7.5)

Regulatory Matters - Other Regu

Regulatory Matters - Other Regulatory Matters (Details) customer in Thousands, $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended	12 Months Ended
	Mar. 31, 2018customer	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Dec. 31, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory assets		$ 4,288	$ 4,370			$ 4,288	$ 4,370
CECONY
Public Utilities, General Disclosures [Line Items]
Regulatory assets		3,924	3,987			3,924	$ 3,987
CECONY | Electric | Hurricane
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer	209
Restoration costs						133
Operation and maintenance expenses						15
Operation and maintenance expenses charged against a storm reserve						84
Capital expenditures		29				29
Removal costs						6
O&R | Electric | Hurricane
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer	93
Restoration costs						43
RECO | Electric | Hurricane
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer	44
Restoration costs						17
NYSPSC | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA			311
Impact in regulatory liability resulting from TCJA		2,489
NYSPSC | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA					$ 259
NYSPSC | CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA			$ 90
Impact in regulatory liability resulting from TCJA		804
NYSPSC | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA					113
NYSPSC | CECONY | Steam
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA				$ 15
Tax credit, amortization period							3 years
Impact in regulatory liability resulting from TCJA		185
NYSPSC | CECONY | Steam | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA					$ 25
NYSPSC | CECONY | MTA Subway Power Outage
Public Utilities, General Disclosures [Line Items]
Regulatory costs		270				270
Regulatory assets		239				239
NYSPSC | CECONY | MTA Subway Power Outage | Electric
Public Utilities, General Disclosures [Line Items]
Regulatory costs		$ 31				$ 31

Regulatory Matters - Regulatory

Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	$ 4,245	$ 4,294
Regulatory assets – current	43	76
Total Regulatory Assets	4,288	4,370
Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,166	2,238
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	798	810
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	299	291
MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	239	229
Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	114	101
Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	77	76
Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	75	67
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	63	73
System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	60	72
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	43	17
Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	37	39
Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	36	36
Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	34	36
Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	23	23
Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	20	20
Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	17
Indian Point Energy Center program costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	7	13
Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	6	5
O&R transition bond charges
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	1	2
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	129	129
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	39	36
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	4	40
CECONY
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3,895	3,923
Regulatory assets – current	29	64
Total Regulatory Assets	3,924	3,987
CECONY | Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,052	2,111
CECONY | Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	706	716
CECONY | Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	286	278
CECONY | MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	239	229
CECONY | Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	101	86
CECONY | Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	0
CECONY | Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	75	67
CECONY | Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	45	56
CECONY | System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	59	70
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	37	11
CECONY | Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	37	39
CECONY | Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	36	36
CECONY | Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	32	34
CECONY | Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	23	23
CECONY | Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	18
CECONY | Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	17
CECONY | Indian Point Energy Center program costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	7	13
CECONY | Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	6	5
CECONY | O&R transition bond charges
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	0
CECONY | Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	118	114
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	29	29
CECONY | Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	$ 0	$ 35

Regulatory Matters - Regulato_2

Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 4,613	$ 4,641
Regulatory liabilities – current	152	114
Total Regulatory Liabilities	4,765	4,755
Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	2,496	2,515
Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	934	928
TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	438	434
Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	124	127
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	115	117
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	62	62
Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	46	6
Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	45	45
System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	31	27
Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	29	37
Property tax reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	26	36
BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	20	18
Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	19	36
Carrying charges on repair allowance and bonus depreciation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	15	21
Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	15	15
New York State income tax rate change
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	12	17
Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	11	7
Base rate change deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	7	10
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	168	183
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	34	53
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	83	31
Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	35	30
CECONY
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	4,220	4,258
Regulatory liabilities – current	105	73
Total Regulatory Liabilities	4,325	4,331
CECONY | Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	2,347	2,363
CECONY | Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	795	790
CECONY | TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	417	411
CECONY | Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	119	122
CECONY | Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	115	117
CECONY | Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	38	40
CECONY | Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	46	6
CECONY | Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	45	45
CECONY | System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	28	24
CECONY | Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	29	37
CECONY | Property tax reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	26	36
CECONY | BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	20	18
CECONY | Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	27
CECONY | Carrying charges on repair allowance and bonus depreciation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	14	21
CECONY | Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	15	15
CECONY | New York State income tax rate change
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	12	17
CECONY | Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	6	7
CECONY | Base rate change deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	7	10
CECONY | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	131	152
CECONY | Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	22	36
CECONY | Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	51	8
CECONY | Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	$ 32	$ 29

Capitalization - Additional Inf

Capitalization - Additional Information (Details) - USD ($)	1 Months Ended		3 Months Ended
	Mar. 31, 2019	Feb. 28, 2019	Mar. 31, 2019	Dec. 31, 2018
Schedule of Capitalization [Line Items]
Number of shares of common stock issued (shares)	5,649,369
Issuance of common shares – public offering	$ 425,000,000		$ 425,000,000
Term loan	0		0	$ 825,000,000
PG&E Project
Schedule of Capitalization [Line Items]
Term loan	$ 1,041,000,000		$ 1,041,000,000
Clean Energy Businesses
Schedule of Capitalization [Line Items]
Non-recourse debt				2,076,000,000
Clean Energy Businesses | Long-term debt due within one year
Schedule of Capitalization [Line Items]
Non-recourse debt				1,965,000,000
Clean Energy Businesses | Long-term debt
Schedule of Capitalization [Line Items]
Non-recourse debt				$ 111,000,000
Term Loan
Schedule of Capitalization [Line Items]
Face amount of debt		$ 825,000,000
Debt term		2 years

Capitalization - Carrying Amoun

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Unamortized debt expense	$ 181	$ 185
Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	18,962	18,145
Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	20,304	18,740
CECONY
Debt Instrument [Line Items]
Unamortized debt discount	137	139
CECONY | Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	14,153	14,151
CECONY | Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	$ 15,371	$ 14,685

Short-Term Borrowing (Details)

Short-Term Borrowing (Details) - USD ($)	Apr. 30, 2019	Mar. 31, 2019	Dec. 31, 2018
Short-term Debt [Line Items]
Commercial paper, outstanding		$ 1,435,000,000	$ 1,741,000,000
Loans outstanding under the credit agreement		$ 0	$ 0
Revolving Credit | Subsequent Event
Short-term Debt [Line Items]
Aggregate commitment	$ 2,200,000,000
Commercial Paper
Short-term Debt [Line Items]
Weighted average interest rate		2.70%	3.00%
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding		$ 1,085,000,000	$ 1,192,000,000
CECONY | Commercial Paper
Short-term Debt [Line Items]
Weighted average interest rate		2.70%	3.00%

Pension Benefits - Total Period

Pension Benefits - Total Periodic Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 62	$ 72
Interest cost on projected benefit obligation	150	140
Expected return on plan assets	(247)	(258)
Recognition of net actuarial loss	130	172
Recognition of prior service cost/(credit)	(4)	(4)
TOTAL PERIODIC BENEFIT COST	91	122
Cost capitalized	(26)	(31)
Reconciliation to rate level	(5)	(23)
Total expense/(credit) recognized	60	68
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	58	68
Interest cost on projected benefit obligation	141	131
Expected return on plan assets	(234)	(245)
Recognition of net actuarial loss	123	163
Recognition of prior service cost/(credit)	(5)	(5)
TOTAL PERIODIC BENEFIT COST	83	112
Cost capitalized	(24)	(29)
Reconciliation to rate level	(4)	(25)
Total expense/(credit) recognized	$ 55	$ 58

Pension Benefits - Additional I

Pension Benefits - Additional Information (Details) - Pension Benefits $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)
Defined Benefit Plan Disclosure [Line Items]
Estimated future employer contributions	$ 350
Contributions	4
CECONY
Defined Benefit Plan Disclosure [Line Items]
Estimated future employer contributions	318
Contributions	$ 3

Other Postretirement Benefits -

Other Postretirement Benefits - Periodic Postretirement Benefit Costs (Details) - Other Postretirement Benefits - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 4	$ 5
Interest cost on accumulated other postretirement benefit obligation	11	11
Expected return on plan assets	(16)	(18)
Recognition of net actuarial loss/(gain)	(2)	2
Recognition of prior service cost/(credit)	(1)	(2)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT)	(4)	(2)
Cost capitalized	(2)	(2)
Reconciliation to rate level	3	2
Total expense/(credit) recognized	(3)	(2)
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	3
Interest cost on accumulated other postretirement benefit obligation	9	9
Expected return on plan assets	(14)	(16)
Recognition of net actuarial loss/(gain)	(2)	1
Recognition of prior service cost/(credit)	0	(1)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT)	(4)	(4)
Cost capitalized	(2)	(2)
Reconciliation to rate level	2	3
Total expense/(credit) recognized	$ (4)	$ (3)

Other Postretirement Benefits_2

Other Postretirement Benefits - Additional Information (Details) - Other Postretirement Benefits $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)
Defined Benefit Plan Disclosure [Line Items]
Contributions	$ 10
CECONY
Defined Benefit Plan Disclosure [Line Items]
Contributions	$ 7

Environmental Matters - Accrued

Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Site Contingency [Line Items]
Accrued liabilities	$ 776	$ 779
Regulatory assets	4,288	4,370
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued liabilities	687	689
Other Superfund Sites
Site Contingency [Line Items]
Accrued liabilities	89	90
Superfund Sites
Site Contingency [Line Items]
Accrued liabilities	776	779
Regulatory assets	798	810
CECONY
Site Contingency [Line Items]
Accrued liabilities	691	693
Regulatory assets	3,924	3,987
CECONY | Manufactured gas plant sites
Site Contingency [Line Items]
Accrued liabilities	602	603
CECONY | Other Superfund Sites
Site Contingency [Line Items]
Accrued liabilities	89	90
CECONY | Superfund Sites
Site Contingency [Line Items]
Accrued liabilities	691	693
Regulatory assets	$ 706	$ 716

Environmental Matters - Environ

Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 3	$ 3
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 2	$ 3

Environmental Matters - Additio

Environmental Matters - Additional Information (Details) - USD ($) $ in Billions	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
CECONY | Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)	15 years
Superfund Sites | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)		$ 2.8
Superfund Sites | Manufactured Gas Plant Sites | Maximum | CECONY
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)		$ 2.6

Environmental Matters - Accru_2

Environmental Matters - Accrued Liability (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Site Contingency [Line Items]
Regulatory assets	$ 4,288	$ 4,370
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers’ Compensation
Site Contingency [Line Items]
Accrued liability	80	79
Regulatory assets	6	5
CECONY
Site Contingency [Line Items]
Regulatory assets	3,924	3,987
CECONY | Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY | Workers’ Compensation
Site Contingency [Line Items]
Accrued liability	76	75
Regulatory assets	$ 6	$ 5

Other Material Contingencies -

Other Material Contingencies - Manhattan Explosion and Fire (Details) $ in Millions	Mar. 12, 2014buildingpeople	Feb. 28, 2017USD ($)	Mar. 31, 2019USD ($)lawsuit	Dec. 31, 2018USD ($)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 4,613	$ 4,641
Settlement of Gas Proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 15	$ 15
Manhattan Explosion and Fire
Loss Contingencies [Line Items]
Number of buildings destroyed by fire | building	2
Number of people died in explosion and fire incident | people	8
Number of people injured in explosion and fire incident (more than) | people	50
Amount of costs that will not recover from customers		$ 126
Number of pending lawsuits | lawsuit			80
Manhattan Explosion and Fire | Settlement of Gas Proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability		$ 27

Other Material Contingencies _2

Other Material Contingencies - Manhattan Steam Main Rupture (Details) $ in Millions	Mar. 31, 2019USD ($)
Property Damage, Clean Up and Other Response Costs Related with Manhattan Steam Main Rupture
Loss Contingencies [Line Items]
Loss contingency	$ 16
Capital, Retirement and Other Costs Related with Manhattan Steam Main Rupture
Loss Contingencies [Line Items]
Loss contingency	$ 9

Other Material Contingencies _3

Other Material Contingencies - Guarantees (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 2,199	$ 2,439
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	876
Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	709
Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	544
Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	70
0 – 3 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,241
0 – 3 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	539
0 – 3 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	490
0 – 3 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	142
0 – 3 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	70
4 – 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	356
4 – 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	337
4 – 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	19
4 – 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
4 – 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
Greater than 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	602
Greater than 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
Greater than 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	200
Greater than 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	402
Greater than 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 0

Other Material Contingencies _4

Other Material Contingencies - Con Edison Transmission (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Dec. 31, 2014
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,199	$ 2,439
Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Ownership interest, percentage			45.70%
Estimated project cost percentage	175.00%
Financial Guarantee in Behalf of CET Gas for Proposed Gas Transmission Project
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 124

Other Material Contingencies _5

Other Material Contingencies - Other (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,199	$ 2,439
Financial Guarantee for Indemnity Agreements for Surety Bonds
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 70

Leases - Additional Information

Leases - Additional Information (Details) $ in Millions	Mar. 31, 2019USD ($)
Lessee, Lease, Description [Line Items]
Assets under finance leases	$ 2
Finance leases, accumulated depreciation	4
CECONY
Lessee, Lease, Description [Line Items]
Assets under finance leases	1
Finance leases, accumulated depreciation	$ 3
Minimum
Lessee, Lease, Description [Line Items]
Lease, term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Lease, term	35 years
Lease, renewal term	5 years

Leases - Lease Cost and Cash Fl

Leases - Lease Cost and Cash Flows (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 21
Operating lease cash flows	8
CECONY
Lessee, Lease, Description [Line Items]
Operating lease cost	16
Operating lease cash flows	$ 4

Leases - Other Related Informat

Leases - Other Related Information (Details)	Mar. 31, 2019
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	19 years 3 months 19 days
Weighted Average Remaining Lease Term, Finance leases	10 years
Weighted Average Discount Rate, Operating leases	4.30%
Weighted Average Discount Rate, Finance leases	4.20%
CECONY
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	14 years 8 months 12 days
Weighted Average Remaining Lease Term, Finance leases	2 years 6 months
Weighted Average Discount Rate, Operating leases	3.60%
Weighted Average Discount Rate, Finance leases	5.30%

Leases - Future Minimum Lease P

Leases - Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Operating Leases
2020	$ 79
2021	74
2022	71
2023	69
2024	68
All years thereafter	973
Total future minimum lease payments	1,334
Less: imputed interest	(459)
Total	875
Operating lease liabilities (current)	50	$ 0
Operating lease liabilities (noncurrent)	825	0
Total	875
Finance Leases
2020	1
2021	0
2022	0
2023	0
2024	0
All years thereafter	1
Total future minimum lease payments	2
Less: imputed interest	0
Total	2
Other current liabilities	1
Other noncurrent liabilities	1
Total	2
CECONY
Operating Leases
2020	58
2021	58
2022	55
2023	53
2024	53
All years thereafter	553
Total future minimum lease payments	830
Less: imputed interest	(191)
Total	639
Operating lease liabilities (current)	41	0
Operating lease liabilities (noncurrent)	598	$ 0
Total	639
Finance Leases
2020	1
2021	0
2022	0
2023	0
2024	0
All years thereafter	0
Total future minimum lease payments	1
Less: imputed interest	0
Total	1
Other current liabilities	1
Other noncurrent liabilities	0
Total	$ 1

Leases - Future Minimum Lease C

Leases - Future Minimum Lease Commitments Under Topic 840 (Details) $ in Millions	Dec. 31, 2018USD ($)
Operating Leased Assets [Line Items]
2019	$ 72
2020	72
2021	71
2022	68
2023	68
All years thereafter	890
Total	1,241
CECONY
Operating Leased Assets [Line Items]
2019	56
2020	56
2021	54
2022	53
2023	53
All years thereafter	592
Total	$ 864

Income Tax - Additional Informa

Income Tax - Additional Information (Details) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Taxes Disclosure [Line Items]
Income tax expense	$ 108,000,000	$ 117,000,000
Estimated liability for uncertain tax positions	7,000,000
Effective income tax rate reconciliation, uncertainty of taxes	4,000,000
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate	7,000,000
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate, net of federal taxes	6,000,000
Interest expense on uncertain tax positions	0
Penalties for uncertain tax positions	0
CECONY
Income Taxes Disclosure [Line Items]
Income tax expense	124,000,000	$ 119,000,000
Estimated liability for uncertain tax positions	4,000,000
Effective income tax rate reconciliation, uncertainty of taxes	$ 2,000,000

Income Tax - Income Tax Reconci

Income Tax - Income Tax Reconciliation (Details)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
STATUTORY TAX RATE
Federal	21.00%	21.00%
Changes in computed taxes resulting from:
State income tax	5.00%	4.00%
Cost of removal	1.00%	1.00%
Other plant-related items	(1.00%)	0.00%
Renewable energy credits	(1.00%)	(1.00%)
Amortization of excess deferred federal income taxes	(4.00%)	(3.00%)
Other	(1.00%)	(1.00%)
Effective tax rate	20.00%	21.00%
CECONY
STATUTORY TAX RATE
Federal	21.00%	21.00%
Changes in computed taxes resulting from:
State income tax	6.00%	5.00%
Cost of removal	1.00%	1.00%
Other plant-related items	0.00%	(1.00%)
Renewable energy credits	(0.00%)	(0.00%)
Amortization of excess deferred federal income taxes	(4.00%)	(3.00%)
Other	(1.00%)	0.00%
Effective tax rate	23.00%	23.00%

Financial Information by Busi_3

Financial Information by Business Segment (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Segment Reporting Information [Line Items]
Total revenues	$ 3,514	$ 3,364
Depreciation and amortization	413	348
Operating income/(loss)	786	755
Clean Energy Businesses
Segment Reporting Information [Line Items]
Depreciation and amortization	58	19
Operating income/(loss)	11	9
Con Edison Transmission
Segment Reporting Information [Line Items]
Operating income/(loss)	(2)	(1)
CECONY
Segment Reporting Information [Line Items]
Total revenues	3,039	2,884
Depreciation and amortization	334	310
Operating income/(loss)	726	705
CECONY | Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	257	240
Operating income/(loss)	257	254
CECONY | Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	55	49
Operating income/(loss)	344	321
CECONY | Steam
Segment Reporting Information [Line Items]
Depreciation and amortization	22	21
Operating income/(loss)	125	130
O&R
Segment Reporting Information [Line Items]
Depreciation and amortization	21	19
Operating income/(loss)	54	44
O&R | Electric
Segment Reporting Information [Line Items]
Depreciation and amortization	15	14
Operating income/(loss)	16	8
O&R | Gas
Segment Reporting Information [Line Items]
Depreciation and amortization	6	5
Operating income/(loss)	38	36
Operating segment
Segment Reporting Information [Line Items]
Total revenues	3,514	3,364
Operating segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Total revenues	217	233
Operating segment | Con Edison Transmission
Segment Reporting Information [Line Items]
Total revenues	1	1
Operating segment | CECONY
Segment Reporting Information [Line Items]
Total revenues	3,039	2,884
Operating segment | CECONY | Electric
Segment Reporting Information [Line Items]
Total revenues	1,797	1,729
Operating segment | CECONY | Gas
Segment Reporting Information [Line Items]
Total revenues	921	841
Operating segment | CECONY | Steam
Segment Reporting Information [Line Items]
Total revenues	321	314
Operating segment | O&R
Segment Reporting Information [Line Items]
Total revenues	258	246
Operating segment | O&R | Electric
Segment Reporting Information [Line Items]
Total revenues	145	149
Operating segment | O&R | Gas
Segment Reporting Information [Line Items]
Total revenues	113	97
Other
Segment Reporting Information [Line Items]
Total revenues	(1)	0
Depreciation and amortization	0	0
Operating income/(loss)	(3)	(2)
Inter-segment | CECONY
Segment Reporting Information [Line Items]
Total revenues	(24)	(24)
Inter-segment | CECONY | Electric
Segment Reporting Information [Line Items]
Total revenues	4	4
Inter-segment | CECONY | Gas
Segment Reporting Information [Line Items]
Total revenues	2	1
Inter-segment | CECONY | Steam
Segment Reporting Information [Line Items]
Total revenues	$ 18	$ 19

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	$ 465	$ 446
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(97)	(66)
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/(Liabilities)	(44)	(23)
Gross Amounts Offset	(3)	(1)
Net Amounts of Assets/ (Liabilities)	(47)	(24)
Margin deposits	4	7
Interest Rate Swap
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	1	2
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(14)	(6)
CECONY
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	433	407
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/(Liabilities)	(24)	(7)
Gross Amounts Offset	(1)	1
Net Amounts of Assets/ (Liabilities)	(25)	(6)
Margin deposits	4	6
Fair Value of Derivative Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(78)	(61)
Gross Amounts Offset	32	11
Net Amounts of Assets/ (Liabilities)	(46)	(50)
Fair Value of Derivative Liabilities, Current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(53)	(31)
Gross Amounts Offset	29	6
Net Amounts of Assets/ (Liabilities)	(24)	(25)
Fair Value of Derivative Liabilities, Noncurrent
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(44)	(19)
Gross Amounts Offset	7	9
Net Amounts of Assets/ (Liabilities)	(37)	(10)
Fair Value of Derivative Liabilities, Noncurrent | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(37)	(12)
Gross Amounts Offset	5	6
Net Amounts of Assets/ (Liabilities)	(32)	(6)
Fair Value of Derivative Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(122)	(80)
Gross Amounts Offset	39	20
Net Amounts of Assets/ (Liabilities)	(83)	(60)
Fair Value of Derivative Liabilities | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(90)	(43)
Gross Amounts Offset	34	12
Net Amounts of Assets/ (Liabilities)	(56)	(31)
Fair Value of Derivative Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	72	43
Gross Amounts Offset	(37)	(14)
Net Amounts of Assets/ (Liabilities)	35	29
Fair Value of Derivative Assets, Current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	62	25
Gross Amounts Offset	(31)	(6)
Net Amounts of Assets/ (Liabilities)	31	19
Fair Value of Derivative Assets, Noncurrent
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	6	14
Gross Amounts Offset	(5)	(7)
Net Amounts of Assets/ (Liabilities)	1	7
Fair Value of Derivative Assets, Noncurrent | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	4	11
Gross Amounts Offset	(4)	(5)
Net Amounts of Assets/ (Liabilities)	0	6
Fair Value of Derivative Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	78	57
Gross Amounts Offset	(42)	(21)
Net Amounts of Assets/ (Liabilities)	36	36
Fair Value of Derivative Assets | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	66	36
Gross Amounts Offset	(35)	(11)
Net Amounts of Assets/ (Liabilities)	$ 31	$ 25

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains (Losses) on Commodity Derivatives (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (1)	$ (24)
Total deferred gains/(losses)	(47)	(74)
Net deferred gains/(losses)	(48)	(98)
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	6	4
Purchased power expense
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	0	0
Gas purchased for resale
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	(3)	0
Non-utility revenue
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	9	4
Non-utility operating revenue
Pre-tax gains/(losses) recognized in income
Unrealized gain/(loss) on derivatives	(1)
Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	5	(22)
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(6)	(2)
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(3)	(48)
Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(18)	25
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(26)	(51)
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(2)	(23)
Total deferred gains/(losses)	(40)	(68)
Net deferred gains/(losses)	(42)	(91)
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	0	0
CECONY | Purchased power expense
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	0	0
CECONY | Gas purchased for resale
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	0	0
CECONY | Non-utility revenue
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	0	0
CECONY | Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	3	(22)
CECONY | Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(5)	(1)
CECONY | Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	(44)
CECONY | Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(14)	25
CECONY | Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (26)	$ (49)

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details) gal in Thousands	Mar. 31, 2019MWgalMWhMMBTU
Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	26,349,795
Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	21,573
Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	140,301,096
Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	8,736
CECONY | Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	24,284,875
CECONY | Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	10,200
CECONY | Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	130,060,000
CECONY | Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	8,736

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Dec. 31, 2016
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 115
Makeup of net credit exposure with investment-grade counterparties	38
Makeup of net credit exposure independent system operators	32
Makeup of net credit exposure non-investment grade/non-rated counterparties	32
Makeup of net credit exposure with commodity exchange brokers	13
Net liability	97	$ 66
Derivative asset	465	446
Interest Rate Swap
Investment Holdings [Line Items]
Net liability	14	6
Derivative asset	1	2
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	11
Makeup of net credit exposure with investment-grade counterparties	5
Makeup of net credit exposure with commodity exchange brokers	6
Derivative asset	433	407
Clean Energy Businesses | Sempra Solar Holding, LLC | Interest Rate Swap
Investment Holdings [Line Items]
Net liability	13	5
Clean Energy Businesses | Coram Wind | Interest Rate Swap
Investment Holdings [Line Items]
Derivative, fixed interest rate			2.0855%
Derivative asset	$ 1	$ 0

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities - Credit-Risk-Related Contingent Features (Details) $ in Millions	Mar. 31, 2019USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 55
Collateral posted	26
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	0
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	44
Derivatives in net asset position additional collateral	14
Additional Collateral Required Due to Loss of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	1
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	42
Collateral posted	19
CECONY | Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	0
CECONY | Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	$ 28

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 465		$ 446
Derivative liabilities	97		66
Transfer out of level 3	0	$ 1
CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	433		407
Transfer out of level 3	0	$ 1
Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(6)		(6)
Derivative liabilities	(6)		(11)
Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(2)		(1)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	312		293
Derivative liabilities	5		8
Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	290		270
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	157		152
Derivative liabilities	77		49
Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	144		137
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2		7
Derivative liabilities	21		20
Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1		1
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	40		43
Derivative liabilities	83		60
Transfer out of level 3			2
Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	35		31
Derivative liabilities	57		32
Transfer out of level 3			2
Commodity | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(6)		(6)
Derivative liabilities	(6)		(11)
Commodity | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(2)		(1)
Derivative liabilities	(4)		(6)
Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	5		6
Derivative liabilities	5		8
Commodity | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3		3
Derivative liabilities	2		5
Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	39		36
Derivative liabilities	63		43
Commodity | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	33		28
Derivative liabilities	53		30
Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2		7
Derivative liabilities	21		20
Commodity | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1		1
Derivative liabilities	6		3
Interest rate swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1		2
Derivative liabilities	14		6
Interest rate swap | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0		0
Derivative liabilities	0		0
Interest rate swap | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0		0
Derivative liabilities	0		0
Interest rate swap | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1		2
Derivative liabilities	14		6
Interest rate swap | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0		0
Derivative liabilities	0		0
Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	424		401
Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	398		376
Other | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0		0
Other | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0		0
Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	307		287
Other | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	287		267
Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	117		114
Other | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	111		109
Other | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0		0
Other | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 0		$ 0

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Commodity Derivatives (Details) $ in Millions	Mar. 31, 2019USD ($)$ / MWh$ / Dt$ / kW-month	Dec. 31, 2018USD ($)
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 465	$ 446
CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	433	407
Level 3
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	2	7
Level 3 | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	1	$ 1
Level 3 | Electricity | Forward energy prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (16)
Level 3 | Electricity | Forward energy prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	20.11
Level 3 | Electricity | Forward energy prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	32.31
Level 3 | Electricity | Forward capacity prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives
Level 3 | Electricity | Forward capacity prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	0.75
Level 3 | Electricity | Forward capacity prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	4.85
Level 3 | Electricity | Forward capacity prices | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (6)
Level 3 | Electricity | Forward capacity prices | CECONY | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	0.75
Level 3 | Electricity | Forward capacity prices | CECONY | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	4.85
Level 3 | Natural Gas | Forward natural gas prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (4)
Level 3 | Natural Gas | Forward natural gas prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / Dt	1.27
Level 3 | Natural Gas | Forward natural gas prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / Dt	2.81
Level 3 | Transmission Congestion Contracts/Financial Transmission Rights | Inter-zonal forward price curves adjusted for historical zonal losses
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Level 3 | Transmission Congestion Contracts/Financial Transmission Rights | Inter-zonal forward price curves adjusted for historical zonal losses | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	0.04
Level 3 | Transmission Congestion Contracts/Financial Transmission Rights | Inter-zonal forward price curves adjusted for historical zonal losses | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	2.90
Level 3 | Transmission Congestion Contracts | Inter-zonal forward price curves adjusted for historical zonal losses | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Level 3 | Transmission Congestion Contracts | Inter-zonal forward price curves adjusted for historical zonal losses | CECONY | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	0.27
Level 3 | Transmission Congestion Contracts | Inter-zonal forward price curves adjusted for historical zonal losses | CECONY | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	2.90
Level 3 | Commodity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (19)
Level 3 | Commodity | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (5)

Fair Value Measurements - Recon

Fair Value Measurements - Reconciliation of Assets and Liabilities Measured at Level 3 Fair Value (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ (13)	$ 1	$ 1
Included in earnings	(4)	2
Included in regulatory assets and liabilities	(5)	2
Settlements	3	(1)
Transfer out of level 3	0	(1)
Ending balance	(19)	3	(13)
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	(2)	4	4
Included in earnings	0	2
Included in regulatory assets and liabilities	(3)	(1)
Settlements	0	(2)
Transfer out of level 3	0	(1)
Ending balance	$ (5)	$ 2	$ (2)

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Details) - Non-utility revenue - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Change in fair value relating to Level 3 commodity derivative assets and liabilities	$ (1)	$ 1
Clean Energy Businesses
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 commodity derivative assets and liabilities	$ (1)	$ 2

Variable Interest Entities - Ad

Variable Interest Entities - Additional Information (Details) - Variable Interest Entity, Primary Beneficiary $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2019USD ($)	Dec. 31, 2018MW
Texas Solar 4
Variable Interest Entity [Line Items]
Generating capacity (MW AC) | MW		40
Tax Equity Projects
Variable Interest Entity [Line Items]
Net income (loss)	$ (19)
Income (loss) before tax	(14)
Con Edison Development | Texas Solar 4
Variable Interest Entity [Line Items]
Percentage of variable interests (less than)		80.00%
Con Edison Development | Tax Equity Projects
Variable Interest Entity [Line Items]
Percentage of variable interests (less than)		100.00%
Tax Equity Investors | Tax Equity Projects
Variable Interest Entity [Line Items]
Net income (loss)	21
Income (loss) before tax	$ 16

Variable Interest Entities - Ne

Variable Interest Entities - Net Assets (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018
Variable Interest Entity [Line Items]
Noncontrolling interest	$ 132	$ 113
Great Valley Solar
Variable Interest Entity [Line Items]
Restricted cash	0	0
Non-utility property, less accumulated depreciation	311	313
Other assets	36	18
Total assets	347	331
Long-term debt due within one year	0	0
Other liabilities	33	17
Long-term debt	0	0
Total liabilities	33	17
Accumulated depreciation	3	1
Great Valley Solar | Tax Equity Investors
Variable Interest Entity [Line Items]
Noncontrolling interest	39	33
Copper Mountain - Mesquite Solar
Variable Interest Entity [Line Items]
Restricted cash	0	0
Non-utility property, less accumulated depreciation	492	492
Other assets	109	97
Total assets	601	589
Long-term debt due within one year	0	0
Other liabilities	45	33
Long-term debt	0	0
Total liabilities	45	33
Accumulated depreciation	4	1
Copper Mountain - Mesquite Solar | Tax Equity Investors
Variable Interest Entity [Line Items]
Noncontrolling interest	83	71
Texas Solar 4
Variable Interest Entity [Line Items]
Restricted cash	6	4
Non-utility property, less accumulated depreciation	95	98
Other assets	10	9
Total assets	111	111
Long-term debt due within one year	2	2
Other liabilities	28	26
Long-term debt	56	56
Total liabilities	86	84
Accumulated depreciation	$ 16	15
Texas Solar 4 | Third Party
Variable Interest Entity [Line Items]
Noncontrolling interest		$ 7	$ 7