10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

FOR THE QUARTERLY PERIOD ENDED September 30, 2021

OR

☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from                      to                     

Commission File Number	Exact name of registrant as specified in its charter and principal executive office address and telephone number					State of Incorporation	I.R.S. Employer ID. Number
1-14514	Consolidated Edison, Inc.					New York	13-3965100
	4 Irving Place,		New York,	New York	10003
	(212)	460-4600
1-1217	Consolidated Edison Company of New York, Inc.					New York	13-5009340
	4 Irving Place,		New York,	New York	10003
	(212)	460-4600

Securities Registered Pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol	Name of each exchange on which registered
Consolidated Edison, Inc.,	ED	New York Stock Exchange
Common Shares ($.10 par value)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Consolidated Edison, Inc. (Con Edison)	Yes	☒	No ☐
Consolidated Edison Company of New York, Inc. (CECONY)	Yes	☒	No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Con Edison	Yes	☒	No ☐
CECONY	Yes	☒	No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer”, “accelerated filer,” “smaller reporting company,” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Con Edison
Large accelerated filer	☒		Accelerated filer ☐		Non-accelerated filer	☐
Smaller reporting company		☐	Emerging growth company	☐
CECONY
Large accelerated filer	☐		Accelerated filer ☐		Non-accelerated filer	☒
Smaller reporting company		☐	Emerging growth company	☐

1

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Con Edison	Yes	☐	No	☒
CECONY	Yes	☐	No	☒

As of October 31, 2021, Con Edison had outstanding 353,748,736 Common Shares ($.10 par value). All of the outstanding common equity of CECONY is held by Con Edison.

Filing Format

This Quarterly Report on Form 10-Q is a combined report being filed separately by two different registrants: Consolidated Edison, Inc. (Con Edison) and Consolidated Edison Company of New York, Inc. (CECONY). CECONY is a wholly-owned subsidiary of Con Edison and, as such, the information in this report about CECONY also applies to Con Edison. As used in this report, the term the “Companies” refers to Con Edison and CECONY. However, CECONY makes no representation as to the information contained in this report relating to Con Edison or the subsidiaries of Con Edison other than itself.

2

Glossary of Terms

The following is a glossary of abbreviations or acronyms that are used in the Companies’ SEC reports:

Con Edison Companies
Con Edison	Consolidated Edison, Inc.
CECONY	Consolidated Edison Company of New York, Inc.
Clean Energy Businesses	Con Edison Clean Energy Businesses, Inc., together with its subsidiaries
Con Edison Transmission	Con Edison Transmission, Inc., together with its subsidiaries
CET Electric	Consolidated Edison Transmission, LLC
CET Gas	Con Edison Gas Pipeline and Storage, LLC
O&R	Orange and Rockland Utilities, Inc.
RECO	Rockland Electric Company
The Companies	Con Edison and CECONY
The Utilities	CECONY and O&R
Regulatory Agencies, Government Agencies and Other Organizations
CPUC	California Public Utilities Commission
EPA	U.S. Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
IASB	International Accounting Standards Board
IRS	Internal Revenue Service
NERC	North American Electric Reliability Corporation
NJBPU	New Jersey Board of Public Utilities
NJDEP	New Jersey Department of Environmental Protection
NYISO	New York Independent System Operator
NYPA	New York Power Authority
NYSDEC	New York State Department of Environmental Conservation
NYSDPS	New York State Department of Public Service
NYSERDA	New York State Energy Research and Development Authority
NYSPSC	New York State Public Service Commission
NYSRC	New York State Reliability Council, LLC
PHMSA	U.S. Department of Transportation’s Pipeline and Hazardous Materials Safety Administration
PJM	PJM Interconnection LLC
SEC	U.S. Securities and Exchange Commission
Accounting
AFUDC	Allowance for Funds Used During Construction
ASU	Accounting Standards Update
GAAP	Generally Accepted Accounting Principles in the United States of America
HLBV	Hypothetical Liquidation at Book Value
NOL	Net Operating Loss
OCI	Other Comprehensive Income
VIE	Variable Interest Entity

3

Environmental
CO2	Carbon dioxide
GHG	Greenhouse gases
MGP Sites	Manufactured gas plant sites
PCBs	Polychlorinated biphenyls
PRP	Potentially responsible party
RGGI	Regional Greenhouse Gas Initiative
Superfund	Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes
Units of Measure
AC	Alternating current
Bcf	Billion cubic feet
Dt	Dekatherms
kV	Kilovolt
kWh	Kilowatt-hour
MDt	Thousand dekatherms
MMlb	Million pounds
MVA	Megavolt ampere
MW	Megawatt or thousand kilowatts
MWh	Megawatt hour
Other
AMI	Advanced metering infrastructure
CARES Act	Coronavirus Aid, Relief, and Economic Security Act, as enacted on March 27, 2020
COSO	Committee of Sponsoring Organizations of the Treadway Commission
COVID-19	Coronavirus Disease 2019
DER	Distributed energy resources
Fitch	Fitch Ratings
First Quarter Form 10-Q	The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended March 31 of the current year
Second Quarter Form 10-Q	The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended June 30 of the current year
Third Quarter Form 10-Q	The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended September 30 of the current year
Form 10-K	The Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2020
LTIP	Long Term Incentive Plan
Moody’s	Moody’s Investors Service, Inc.
REV	Reforming the Energy Vision
S&P	S&P Global Ratings
TCJA	The federal Tax Cuts and Jobs Act of 2017, as enacted on December 22, 2017
VaR	Value-at-Risk

4

TABLE OF CONTENTS

		PAGE
PART I—Financial Information
ITEM 1	Financial Statements (Unaudited)
	Con Edison
	Consolidated Income Statement	7
	Consolidated Statement of Comprehensive Income	8
	Consolidated Statement of Cash Flows	9
	Consolidated Balance Sheet	10
	Consolidated Statement of Equity	12
	CECONY
	Consolidated Income Statement	14
	Consolidated Statement of Comprehensive Income	15
	Consolidated Statement of Cash Flows	16
	Consolidated Balance Sheet	17
	Consolidated Statement of Shareholder’s Equity	19
	Notes to the Financial Statements (Unaudited)	20
ITEM 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	55
ITEM 3	Quantitative and Qualitative Disclosures About Market Risk	94
ITEM 4	Controls and Procedures	94
PART II—Other Information		95
ITEM 1	Legal Proceedings	95
ITEM 1A	Risk Factors	95
ITEM 6	Exhibits	95
	Signatures	96

5

FORWARD-LOOKING STATEMENTS

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

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

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

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

•the failure of, or damage to, the Companies’ facilities could adversely affect the Companies;

•a cyber attack could adversely affect the Companies;

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

•the Companies are exposed to risks from the environmental consequences of their operations, including increased costs related to climate change;

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

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

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

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

•changes to tax laws could adversely affect the Companies;

•the Companies’ strategies may not be effective to address changes in the external business environment;

•the Companies face risks related to health epidemics and other outbreaks, including the COVID-19 pandemic; and

•the Companies also face other risks that are beyond their control, including inflation and supply chain disruptions.

The Companies assume no obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law.

6

Consolidated Edison, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars/Except Share Data)	2021	2020	2021	2020
OPERATING REVENUES
Electric	$2,952	$2,770	$7,180	$6,660
Gas	341	289	1,907	1,673
Steam	55	51	393	385
Non-utility	265	223	781	568
TOTAL OPERATING REVENUES	3,613	3,333	10,261	9,286
OPERATING EXPENSES
Purchased power	548	503	1,448	1,192
Fuel	44	24	166	124
Gas purchased for resale	83	55	461	364
Other operations and maintenance	849	736	2,443	2,116
Depreciation and amortization	512	482	1,511	1,428
Taxes, other than income taxes	727	673	2,103	1,915
TOTAL OPERATING EXPENSES	2,763	2,473	8,132	7,139
OPERATING INCOME	850	860	2,129	2,147
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	5	27	(180)	78
Other income	5	8	19	15
Allowance for equity funds used during construction	5	2	15	12
Other deductions	(37)	(50)	(113)	(177)
TOTAL OTHER INCOME (DEDUCTIONS)	(22)	(13)	(259)	(72)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	828	847	1,870	2,075
INTEREST EXPENSE
Interest on long-term debt	235	227	693	685
Other interest	(2)	4	(15)	122
Allowance for borrowed funds used during construction	(1)	(5)	(9)	(10)
NET INTEREST EXPENSE	232	226	669	797
INCOME BEFORE INCOME TAX EXPENSE	596	621	1,201	1,278
INCOME TAX EXPENSE	127	119	194	183
NET INCOME	469	502	1,007	1,095
Income (loss) attributable to non-controlling interest	(69)	9	(115)	37
NET INCOME FOR COMMON STOCK	$538	$493	$1,122	$1,058
Net income per common share—basic	$1.52	$1.47	$3.23	$3.17
Net income per common share—diluted	$1.52	$1.47	$3.23	$3.16
AVERAGE NUMBER OF SHARES OUTSTANDING—BASIC (IN MILLIONS)	353.4	334.5	346.8	334.1
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS)	354.1	335.4	347.5	335.0

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

7

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	Three Months Ended September 30,		Nine Months Ended September 30,
(Millions of Dollars)	2021	2020	2021	2020
NET INCOME	$469	$502	$1,007	$1,095
LOSS/(INCOME) ATTRIBUTABLE TO NON-CONTROLLING INTEREST	69	(9)	115	(37)
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	2	2	8	7
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	2	2	8	7
COMPREHENSIVE INCOME	$540	$495	$1,130	$1,065

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

8

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Nine Months Ended September 30,
(Millions of Dollars)	2021	2020
OPERATING ACTIVITIES
Net income	$1,007	$1,095
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,511	1,428
Investment loss/impairment	211	—
Deferred income taxes	167	184
Rate case amortization and accruals	(14)	(30)
Common equity component of allowance for funds used during construction	(15)	(12)
Net derivative losses/(gains)	(26)	80
Unbilled revenue and net unbilled revenue deferrals	(72)	29
Other non-cash items, net	108	43
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(387)	(322)
Allowance for uncollectible accounts – customers	165	48
Materials and supplies, including fuel oil and gas in storage	(50)	(1)
Revenue decoupling mechanism receivable	(56)	(52)
Other receivables and other current assets	81	(32)
Taxes receivable	18	(6)
Prepayments	(576)	(517)
Accounts payable	(15)	19
Pensions and retiree benefits obligations	237	181
Pensions and retiree benefits contributions	(467)	(474)
Accrued taxes	(27)	13
Accrued interest	126	102
Superfund and environmental remediation costs	(12)	(8)
Distributions from equity investments	18	29
System benefit charge	3	(56)
Deferred charges, noncurrent assets and other regulatory assets	(705)	(443)
Deferred credits and other regulatory liabilities	578	35
Other current and noncurrent liabilities	(96)	35
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,712	1,368
INVESTING ACTIVITIES
Utility construction expenditures	(2,697)	(2,346)
Cost of removal less salvage	(242)	(216)
Non-utility construction expenditures	(289)	(414)
Investments in electric and gas transmission projects	(16)	—
Investments in/acquisitions of renewable electric production projects	—	(24)
Proceeds from sale of assets	614	—
Divestiture of renewable electric projects, net	183	—
Other investing activities	10	16
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,437)	(2,984)
FINANCING ACTIVITIES
Net issuance of short-term debt	(834)	137
Issuance of long-term debt	1,979	1,675
Retirement of long-term debt	(1,904)	(463)
Debt issuance costs	(30)	(25)
Common stock dividends	(768)	(731)
Issuance of common shares - public offering	775	88
Issuance of common shares for stock plans	45	43
Distribution to noncontrolling interest	(15)	(11)
Sale of equity interest	256	—
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	(496)	713
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(1,221)	(903)
BALANCE AT BEGINNING OF PERIOD	1,436	1,217
BALANCE AT END OF PERIOD	$215	$314
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$565	$583
Income taxes	$(9)	$31
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$388	$432
Issuance of common shares for dividend reinvestment	$37	$36
Software licenses acquired but unpaid as of end of period	$24	$51
Equipment acquired but unpaid as of end of period	$22	$28

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

9

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

(Millions of Dollars)	September 30, 2021	December 31, 2020
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$66	$1,272
Accounts receivable – customers, less allowance for uncollectible accounts of $313 and $148 in 2021 and 2020, respectively	1,923	1,701
Other receivables, less allowance for uncollectible accounts of $7 in 2021 and 2020	272	278
Taxes receivable	8	26
Accrued unbilled revenue	656	599
Fuel oil, gas in storage, materials and supplies, at average cost	405	356
Prepayments	847	271
Regulatory assets	205	266
Restricted cash	149	164
Revenue decoupling mechanism receivable	193	137
Other current assets	372	231
TOTAL CURRENT ASSETS	5,096	5,301
INVESTMENTS	1,078	1,816
UTILITY PLANT, AT ORIGINAL COST
Electric	34,446	33,315
Gas	11,869	10,847
Steam	2,773	2,696
General	4,091	3,880
TOTAL	53,179	50,738
Less: Accumulated depreciation	11,907	11,188
Net	41,272	39,550
Construction work in progress	2,264	2,474
NET UTILITY PLANT	43,536	42,024
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $590 and $522 in 2021 and 2020, respectively	4,202	3,893
Construction work in progress	209	638
NET PLANT	47,947	46,555
OTHER NONCURRENT ASSETS
Goodwill	446	446
Intangible assets, less accumulated amortization of $273 and $228 in 2021 and 2020, respectively	1,317	1,460
Regulatory assets	5,903	6,195
Operating lease right-of-use asset	817	837
Other deferred charges and noncurrent assets	334	285
TOTAL OTHER NONCURRENT ASSETS	8,817	9,223
TOTAL ASSETS	$62,938	$62,895

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

10

Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

(Millions of Dollars)	September 30, 2021	December 31, 2020
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$439	$1,967
Term loan	—	165
Notes payable	1,036	1,705
Accounts payable	1,370	1,475
Customer deposits	286	311
Accrued taxes	123	150
Accrued interest	273	149
Accrued wages	113	108
Fair value of derivative liabilities	163	238
Regulatory liabilities	490	36
System benefit charge	460	528
Operating lease liabilities	113	96
Other current liabilities	389	426
TOTAL CURRENT LIABILITIES	5,255	7,354
NONCURRENT LIABILITIES
Provision for injuries and damages	177	178
Pensions and retiree benefits	1,424	2,257
Superfund and other environmental costs	841	857
Asset retirement obligations	602	576
Fair value of derivative liabilities	166	240
Deferred income taxes and unamortized investment tax credits	6,835	6,475
Operating lease liabilities	756	764
Regulatory liabilities	4,379	4,513
Other deferred credits and noncurrent liabilities	285	234
TOTAL NONCURRENT LIABILITIES	15,465	16,094
LONG-TERM DEBT	21,841	20,382
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	20,037	18,847
Noncontrolling interest	340	218
TOTAL EQUITY (See Statement of Equity)	20,377	19,065
TOTAL LIABILITIES AND EQUITY	$62,938	$62,895

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

11

Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF EQUITY (UNAUDITED)

(In Millions, except for dividends per share)	Common Stock		Additional Paid-In Capital	Retained Earnings	Treasury Stock		Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Non- controlling Interest	Total
	Shares	Amount			Shares	Amount
BALANCE AS OF DECEMBER 31, 2019	333	$35	$8,054	$11,100	23	$(1,038)	$(110)	$(19)	$191	$18,213
Net income				375					17	392
Common stock dividends ($0.76 per share)				(255)						(255)
Issuance of common shares - public offering	1		88							88
Issuance of common shares for stock plans			26							26
Other comprehensive income								5		5
Distributions to noncontrolling interests									(2)	(2)
BALANCE AS OF MARCH 31, 2020	334	$35	$8,168	$11,220	23	$(1,038)	$(110)	$(14)	$206	$18,467
Net income				190					12	202
Common stock dividends ($0.76 per share)				(256)						(256)
Issuance of common shares for stock plans			30							30
Distributions to noncontrolling interest									(2)	(2)
BALANCE AS OF JUNE 30, 2020	334	$35	$8,198	$11,154	23	$(1,038)	$(110)	$(14)	$216	$18,441
Net income				493					9	502
Common stock dividends ($0.76 per share)				(256)						(256)
Issuance of common shares - public offering										—
Issuance of common shares for stock plans			30							30
Other comprehensive income								2		2
Distributions to noncontrolling interest									(8)	(8)
BALANCE AS OF SEPTEMBER 30, 2020	334	$35	$8,228	$11,391	23	$(1,038)	$(110)	$(12)	$217	$18,711
BALANCE AS OF DECEMBER 31, 2020	342	$36	$8,808	$11,178	23	$(1,038)	$(112)	$(25)	$218	$19,065
Net income				419					1	420
Common stock dividends ($0.775 per share)				(265)						(265)
Issuance of common shares for stock plans			28							28
Other comprehensive income								4		4
Distributions to noncontrolling interests									(3)	(3)
Net proceeds from sale of equity interest									33	33
BALANCE AS OF MARCH 31, 2021	342	$36	$8,836	$11,332	23	$(1,038)	$(112)	$(21)	$249	$19,282
Net income (loss)				165					(47)	118
Common stock dividends ($0.775 per share)				(266)						(266)
Issuance of common shares - public offering	11	1	785				(11)			775
Issuance of common shares for stock plans			34							34
Other comprehensive income								2		2
Distributions to noncontrolling interests									(4)	(4)

12

Net proceeds from sale of equity interest									112	112
BALANCE AS OF JUNE 30, 2021	353	$37	$9,655	$11,231	23	$(1,038)	$(123)	$(19)	$310	$20,053
Net income (loss)				538					(69)	469
Common stock dividends ($0.775 per share)				(274)						(274)
Issuance of common shares - public offering	1									—
Issuance of common shares for stock plans			28							28
Other comprehensive income								2		2
Distributions to noncontrolling interests									(8)	(8)
Net proceeds from sale of equity interest									107	107
BALANCE AS OF SEPTEMBER 30, 2021	354	$37	$9,683	$11,495	23	$(1,038)	$(123)	$(17)	$340	$20,377

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

13

Consolidated Edison Company of New York, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars)	2021	2020	2021	2020
OPERATING REVENUES
Electric	$2,730	$2,562	$6,661	$6,178
Gas	307	259	1,730	1,509
Steam	55	51	393	385
TOTAL OPERATING REVENUES	3,092	2,872	8,784	8,072
OPERATING EXPENSES
Purchased power	481	447	1,294	1,065
Fuel	44	24	166	124
Gas purchased for resale	61	38	357	298
Other operations and maintenance	650	597	1,848	1,714
Depreciation and amortization	429	401	1,267	1,187
Taxes, other than income taxes	699	643	2,016	1,830
TOTAL OPERATING EXPENSES	2,364	2,150	6,948	6,218
OPERATING INCOME	728	722	1,836	1,854
OTHER INCOME (DEDUCTIONS)
Investment and other income	5	6	15	11
Allowance for equity funds used during construction	5	1	14	10
Other deductions	(33)	(45)	(99)	(159)
TOTAL OTHER INCOME (DEDUCTIONS)	(23)	(38)	(70)	(138)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	705	684	1,766	1,716
INTEREST EXPENSE
Interest on long-term debt	194	179	564	537
Other interest	3	7	11	26
Allowance for borrowed funds used during construction	—	(4)	(8)	(9)
NET INTEREST EXPENSE	197	182	567	554
INCOME BEFORE INCOME TAX EXPENSE	508	502	1,199	1,162
INCOME TAX EXPENSE	90	97	188	199
NET INCOME	$418	$405	$1,011	$963

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

14

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)

	Three Months Ended September 30,		Nine Months Ended September 30,
(Millions of Dollars)	2021	2020	2021	2020
NET INCOME	$418	$405	$1,011	$963
Pension and other postretirement benefit plan liability adjustments, net of taxes	—	—	—	2
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	—	—	—	2
COMPREHENSIVE INCOME	$418	$405	$1,011	$965

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

15

Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)

	For the Nine Months Ended September 30,
(Millions of Dollars)	2021	2020
OPERATING ACTIVITIES
Net income	$1,011	$963
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,267	1,187
Deferred income taxes	166	201
Rate case amortization and accruals	(13)	(30)
Common equity component of allowance for funds used during construction	(14)	(10)
Unbilled revenue and net unbilled revenue deferrals	2	—
Other non-cash items, net	46	(9)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(383)	(289)
Allowance for uncollectible accounts – customers	162	45
Materials and supplies, including fuel oil and gas in storage	(47)	6
Revenue decoupling mechanism receivable	(64)	(45)
Other receivables and other current assets	35	3
Accounts receivable from affiliated companies	18	(83)
Prepayments	(573)	(481)
Accounts payable	(49)	29
Accounts payable to affiliated companies	1	1
Pensions and retiree benefits obligations	234	169
Pensions and retiree benefits contributions	(430)	(434)
Superfund and environmental remediation costs	(19)	(14)
Accrued taxes	(31)	10
Accrued taxes to affiliated companies	6	3
Accrued interest	103	97
System benefit charge	3	(53)
Deferred charges, noncurrent assets and other regulatory assets	(666)	(420)
Deferred credits and other regulatory liabilities	509	112
Other current and noncurrent liabilities	(23)	1
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,251	959
INVESTING ACTIVITIES
Utility construction expenditures	(2,545)	(2,200)
Cost of removal less salvage	(237)	(212)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,782)	(2,412)
FINANCING ACTIVITIES
Net payment of short-term debt	(718)	(146)
Issuance of long-term debt	1,500	1,600
Retirement of long-term debt	(640)	(350)
Debt issuance costs	(20)	(24)
Capital contribution by parent	1,101	200
Dividend to parent	(741)	(737)
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	482	543
CASH AND TEMPORARY CASH INVESTMENTS
NET CHANGE FOR THE PERIOD	(1,049)	(910)
BALANCE AT BEGINNING OF PERIOD	1,067	933
BALANCE AT END OF PERIOD	$18	$23
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$446	$430
Income taxes	$(2)	$78
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$335	$340
Software licenses acquired but unpaid as of end of period	$22	$48
Equipment acquired but unpaid as of end of period	$22	$28

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

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

(Millions of Dollars)	September 30, 2021	December 31, 2020
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$18	$1,067
Accounts receivable – customers, less allowance for uncollectible accounts of $300 and $138 in 2021 and 2020, respectively	1,816	1,595
Other receivables, less allowance for uncollectible accounts of $5 and $4 in 2021 and 2020, respectively	141	134
Taxes receivable	5	8
Accrued unbilled revenue	506	523
Accounts receivable from affiliated companies	116	134
Fuel oil, gas in storage, materials and supplies, at average cost	338	291
Prepayments	732	159
Regulatory assets	187	244
Revenue decoupling mechanism receivable	193	129
Other current assets	297	123
TOTAL CURRENT ASSETS	4,349	4,407
INVESTMENTS	597	541
UTILITY PLANT, AT ORIGINAL COST
Electric	32,367	31,327
Gas	10,904	9,921
Steam	2,773	2,696
General	3,777	3,585
TOTAL	49,821	47,529
Less: Accumulated depreciation	10,961	10,297
Net	38,860	37,232
Construction work in progress	2,123	2,320
NET UTILITY PLANT	40,983	39,552
NON-UTILITY PROPERTY
Non-utility property, less accumulated depreciation of $25 in 2021 and 2020	2	2
NET PLANT	40,985	39,554
OTHER NONCURRENT ASSETS
Regulatory assets	5,473	5,745
Operating lease right-of-use asset	552	578
Other deferred charges and noncurrent assets	222	142
TOTAL OTHER NONCURRENT ASSETS	6,247	6,465
TOTAL ASSETS	$52,178	$50,967

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

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)

(Millions of Dollars)	September 30, 2021	December 31, 2020
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$—	$640
Notes payable	942	1,660
Accounts payable	1,101	1,232
Accounts payable to affiliated companies	23	22
Customer deposits	272	296
Accrued taxes	101	132
Accrued taxes to affiliated companies	7	1
Accrued interest	229	126
Accrued wages	103	97
Fair value of derivative liabilities	114	163
Regulatory liabilities	428	11
System benefit charge	407	475
Operating lease liabilities	85	73
Other current liabilities	315	319
TOTAL CURRENT LIABILITIES	4,127	5,247
NONCURRENT LIABILITIES
Provision for injuries and damages	171	172
Pensions and retiree benefits	1,179	1,943
Superfund and other environmental costs	765	780
Asset retirement obligations	529	508
Fair value of derivative liabilities	97	105
Deferred income taxes and unamortized investment tax credits	6,770	6,411
Operating lease liabilities	507	512
Regulatory liabilities	3,941	4,094
Other deferred credits and noncurrent liabilities	235	197
TOTAL NONCURRENT LIABILITIES	14,194	14,722
LONG-TERM DEBT	17,637	16,149
COMMITMENTS AND CONTINGENCIES (Note B, Note G and Note H)
SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	16,220	14,849
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$52,178	$50,967

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

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF SHAREHOLDER’S EQUITY (UNAUDITED)

	Common Stock		Additional Paid-In Capital	Retained Earnings	Repurchased Con Edison Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Total
(In Millions)	Shares	Amount
BALANCE AS OF DECEMBER 31, 2019	235	$589	$5,669	$8,919	$(962)	$(62)	$(6)	$14,147
Net income				406				406
Common stock dividend to parent				(246)				(246)
Capital contribution by parent			25					25
Other comprehensive income							1	1
BALANCE AS OF MARCH 31, 2020	235	$589	$5,694	$9,079	$(962)	$(62)	$(5)	$14,333
Net income				152				152
Common stock dividend to parent				(246)				(246)
Capital contribution by parent			25					25
Other comprehensive income							1	1
BALANCE AS OF JUNE 30, 2020	235	$589	$5,719	$8,985	$(962)	$(62)	$(4)	$14,265
Net income				405				405
Common stock dividend to parent				(245)				(245)
Capital contribution by parent			150					150
Other comprehensive income							—	—
BALANCE AS OF SEPTEMBER 30, 2020	235	$589	$5,869	$9,145	$(962)	$(62)	$(4)	$14,575
BALANCE AS OF DECEMBER 31, 2020	235	$589	$6,169	$9,122	$(962)	$(62)	$(7)	$14,849
Net income				465				465
Common stock dividend to parent				(247)				(247)
Capital contribution by parent			125					125
BALANCE AS OF MARCH 31, 2021	235	$589	$6,294	$9,340	$(962)	$(62)	$(7)	$15,192
Net income				128				128
Common stock dividend to parent				(247)				(247)
Capital contribution by parent			851					851
BALANCE AS OF JUNE 30, 2021	235	$589	$7,145	$9,221	$(962)	$(62)	$(7)	$15,924
Net income				418				418
Common stock dividend to parent				(247)				(247)
Capital contribution by parent			125					125
BALANCE AS OF SEPTEMBER 30, 2021	235	$589	$7,270	$9,392	$(962)	$(62)	$(7)	$16,220

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

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NOTES TO THE FINANCIAL STATEMENTS (UNAUDITED)

General

These combined notes accompany and form an integral part of the separate interim 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 statement 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, 2020 and their separate unaudited financial statements (including the combined notes thereto) included in Part 1, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2021 and June 30, 2021.

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., through its subsidiaries, develops, owns and operates renewable and sustainable energy infrastructure projects and provides energy-related products and services to wholesale and retail customers. Con Edison Transmission, Inc. invests in and seeks to develop electric transmission projects through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and manages, through joint ventures, investments in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See “Investments” in Note A and Note R.

Note A – Summary of Significant Accounting Policies and Other Matters

Accounting Policies

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

Investments

Con Edison's investments consist primarily of the investments of Con Edison Transmission that are accounted for under the equity method and the fair value of the Utilities' supplemental retirement income plan and deferred income plan assets.

Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach)

In May 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET Gas) entered into a purchase and sale agreement pursuant to which the subsidiary and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $612.5 million will be CET Gas' portion for its 50 percent interest, subject to closing adjustments. The purchase and sale agreement contemplates a two-stage closing, the first of which was completed in July 2021 for a sale price of $1,195 million, of which $614 million, including working capital, was attributed to CET Gas. The second closing for the remaining $30 million, of which $15 million will be attributed to CET Gas, subject to closing adjustments, is to occur following approval by the New York State Public Service Commission, which is expected later this year or during the first quarter of 2022, subject to customary closing conditions.

As a result of information made available to Stagecoach as part of the sale process, Stagecoach performed impairment tests that resulted in Stagecoach recording impairment charges of $414 million for the nine months ended September 30, 2021. Accordingly, Con Edison recorded pre-tax impairment losses on its 50 percent interest

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in Stagecoach of $211 million ($147 million after-tax), including working capital and transaction cost adjustments, within "Investment income/(loss)" on Con Edison's consolidated income statement for the nine months ended September 30, 2021. These charges reduced the carrying value of Con Edison’s investment in Stagecoach to $630 million at June 30, 2021.

Stagecoach’s impairment charges and information obtained from the sales process constituted triggering events for Con Edison's investment in Stagecoach as of March 31, 2021 and June 30, 2021. Con Edison evaluated the carrying value of its investment in Stagecoach for other-than-temporary declines in value using income and market-based approaches. Con Edison determined that the carrying value of its investment in Stagecoach of $667 million and $630 million as of March 31, 2021 and June 30, 2021, respectively, was not impaired. The carrying value of $630 million at June 30, 2021 approximates the final sales price received in July 2021 and the remaining amount expected to be received, including closing adjustments.

The accounting rules require Con Edison to evaluate its investments periodically to determine whether they are impaired. The standard for determining whether an impairment exists and must be recorded is whether an other-than-temporary decline in carrying value has occurred. Changes in economic conditions, forecasted cash flows and the regulatory environment, among other factors, could require equity method investments to recognize a decrease in carrying value for an other-than-temporary decline. When management believes such a decline may have occurred, the fair value of the investment is estimated using market inputs, when observable, or a market valuation model such as a discounted cash flow analysis. The fair value is compared to the carrying value of the investment in order to determine the amount of impairment to record, if any.

The evaluation and measurement of impairments involve uncertainties. The judgments that Con Edison makes to estimate the fair value of its equity method investments are based on assumptions that management believes are reasonable, and variations in these estimates or the underlying assumptions, or the receipt of additional market information, could have a material impact on whether a triggering event is determined to exist or the amount of any such impairment. Additionally, if the projects in which Con Edison holds these investments recognize an impairment, Con Edison may record a share of that impairment loss and would evaluate its investment for an other-than-temporary decline in carrying value as described above.

Reclassification

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

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 is 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 and nine months ended September 30, 2021 and 2020, basic and diluted EPS for Con Edison were calculated as follows:

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2021	2020	2021	2020
Net income for common stock	$538	$493	$1,122	$1,058
Weighted average common shares outstanding – basic	353.4	334.5	346.8	334.1
Add: Incremental shares attributable to effect of potentially dilutive securities	0.7	0.9	0.7	0.9
Adjusted weighted average common shares outstanding – diluted	354.1	335.4	347.5	335.0
Net Income per common share – basic	$1.52	$1.47	$3.23	$3.17
Net Income per common share – diluted	$1.52	$1.47	$3.23	$3.16

The computation of diluted EPS for the three and nine months ended September 30, 2021 and 2020 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect.

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Changes in Accumulated Other Comprehensive Income/(Loss) by Component

For the three and nine months ended September 30, 2021 and 2020, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance, accumulated OCI, net of taxes (a)	$(19)	$(14)	$(7)	$(4)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2021 and 2020 (a)(b)	2	2	—	—
Current period OCI, net of taxes	2	2	—	—
Ending balance, accumulated OCI, net of taxes (a)	$(17)	$(12)	$(7)	$(4)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance, accumulated OCI, net of taxes (a)	$(25)	$(19)	$(7)	$(6)
OCI before reclassifications, net of tax of $(1) for Con Edison in 2021 and 2020	2	4	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2021 and 2020 (a)(b)	6	3	—	2
Current period OCI, net of taxes	8	7	—	2
Ending balance, accumulated OCI, net of taxes (a)	$(17)	$(12)	$(7)	$(4)

(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 and liabilities 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 costs. 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 September 30, 2021 and 2020, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows:

	At September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Cash and temporary cash investments	$66	$153	$18	$23
Restricted cash (a)	149	161	—	—
Total cash, temporary cash investments and restricted cash	$215	$314	$18	$23

(a)Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($149 million and $161 million at September 30, 2021 and 2020, respectively) that, under the related project debt agreements, is restricted to being used for normal operating expenses and capital expenditures, debt service, and required reserves until the various maturity dates of the project debt.

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Note B – Regulatory Matters

Rate Plans

In October 2021, O&R, the New York State Department of Public Service (NYSDPS) and other parties entered into a Joint Proposal for new electric and gas rate plans for the three-year period January 2022 through December 2024 (the Joint Proposal). The Joint Proposal is subject to NYSPSC approval. The Joint Proposal includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over 3 years ($2.8 million); reconciliation of late payment charges to amounts reflected in rates for years 2021 through 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity; and reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates from January 1, 2020 through December 31, 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity. The following tables contain a summary of the proposed rate plans.

O&R New York – Electric
Effective period	January 2022 – December 2024 (c)
Base rate changes	Yr. 1 – $4.9 million (a) Yr. 2 – $16.2 million (a) Yr. 3 – $23.1 million (a)
Amortizations to income of net regulatory (assets) and liabilities (b)	Yr. 1 – $11.8 million Yr. 2 – $13.5 million Yr. 3 – $15.2 million
Other revenue sources	Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $3.3 million Yr. 2 – $2.3 million Yr. 3 – $4.0 million
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $4.3 million Yr. 2 – $4.4 million Yr. 3 – $5.1 million
Cost reconciliations	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (d), energy efficiency program (e), major storms, and certain other costs to amounts reflected in rates.
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target Yr. 1 – $1,175 million Yr. 2 – $1,198 million Yr. 3 – $1,304 million
Average rate base	Yr. 1 – $1,021 million Yr. 2 – $1,044 million Yr. 3 – $1,144 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent
Authorized return on common equity	9.2 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.7 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent
Common equity ratio	48 percent

(a) The Joint Proposal recommends that these base rate changes may be implemented with increases of: Yr. 1 - $11.7 million; Yr. 2 - $11.7 million; and Yr. 3 - $11.7 million.

(b) Reflects amortization of, among other things, previously incurred incremental deferred storm costs over a five-year period. See "Other Regulatory Matters," below.

(c) If at the end of any year, Con Edison’s investments in its non-utility businesses exceed 15 percent of Con Edison’s total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, O&R is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures are not necessary.

(d) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(e) Energy efficiency costs are expensed as incurred. Such costs are subject to a cumulative reconciliation that is evenly distributed over the term of the rate plan subject to the caps set forth in the January 2020 NYSPSC New Efficiency New York (“NENY”) order. If the NYSPSC modifies O&R's NENY budgets during the rate term, such modifications will be reflected at the time of the cumulative reconciliations.

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O&R New York – Gas
Effective period	January 2022 – December 2024 (b)
Base rate changes	Yr. 1 – $0.7 million (a) Yr. 2 – $7.4 million (a) Yr. 3 – $9.9 million (a)
Amortization to income of net regulatory (assets) and liabilities	Yr. 1 – $0.8 million Yr. 2 – $0.7 million Yr. 3 – $0.3 million
Other revenue sources	Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $0.2 million Yr. 2 - $0.2 million Yr. 3 - $0.4 million Potential positive rate adjustment for gas safety and performance of up to: Yr. 1 – $1.2 million Yr. 2 – $1.3 million Yr. 3 – $1.4 million
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $6.3 million Yr. 2 – $6.7 million Yr. 3 – $7.3 million
Cost reconciliations	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (c), energy efficiency program (d), major storms and certain other costs to amounts reflected in rates.
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target Yr. 1 – $720 million Yr. 2 – $761 million Yr. 3 – $803 million
Average rate base	Yr. 1 – $566 million Yr. 2 – $607 million Yr. 3 – $649 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent
Authorized return on common equity	9.2 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.7 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent
Common equity ratio	48 percent

(a) The Joint Proposal recommends that these base rate changes may be implemented with increases of: Yr. 1 – $4.4 million; Yr. 2 - $4.4 million; and Yr. 3 - $4.4 million.

(b) If at the end of any year, Con Edison’s investments in its non-utility businesses exceed 15 percent of Con Edison’s total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, O&R is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures are not necessary.

(c) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(d) Energy efficiency costs are expensed as incurred. Such costs are subject to a cumulative reconciliation that is evenly distributed over the term of the rate plan subject to the caps set forth in the January 2020 NYSPSC New Efficiency New York (“NENY”) order. If the NYSPSC modifies O&R’s NENY budgets during the rate term, such modifications will be reflected at the time of the cumulative reconciliations.

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Rockland Electric Company (RECO)

In May 2021, RECO filed a request with the New Jersey Board of Public Utilities (NJBPU) for an electric rate increase of $16.9 million, effective February 2022. The filing reflected a return on common equity of 10.00 percent and a common equity ratio of 49.25 percent. RECO also seeks an increase in its annual storm allowance of $1 million, recovery of deferred costs associated with Tropical Storm Isaias, and the collection of various deferred COVID-19 related costs. In October 2021, RECO filed an update to the request it filed in May 2021. The company increased its requested February 2022 rate increase to $19.5 million and decreased the common equity ratio to 48.84 percent. The updated filing continues to reflect a return on common equity of 10.00 percent.

In September 2021, RECO requested authorization from the NJBPU to defer $3.7 million in incremental storm preparation costs for Tropical Storm Henri.

COVID-19 Regulatory Matters

Governors, public utility commissions and other regulatory agencies in the states in which the Utilities operate have issued orders related to the COVID-19 pandemic that impact the Utilities as described below.

New York State Regulation

In March 2020, former New York State Governor Cuomo declared a State Disaster Emergency for the State of New York due to the COVID-19 pandemic and signed the "New York State on PAUSE" executive order that temporarily closed all non-essential businesses statewide. The former Governor then lifted these closures over time and ended the emergency declaration in June 2021. As a result of the emergency declaration, and due to economic conditions, the NYSPSC and the Utilities have worked to mitigate the potential impact of the COVID-19 pandemic on the Utilities, their customers and other stakeholders.

In March 2020, the Utilities began suspending service disconnections, certain collection notices, final bill collection agency activity, new late payment charges and certain other fees for all customers. The Utilities also began providing payment extensions for all customers that were scheduled to be disconnected prior to the start of the COVID-19 pandemic. In June 2020, the state of New York enacted a law prohibiting New York utilities, including CECONY and O&R, from disconnecting residential customers, and starting in May 2021 small business customers, during the COVID-19 state of emergency, which ended in June 2021. In addition, such prohibitions will apply for an additional 180 days after the state of emergency ends (December 21, 2021) for residential and small business customers who have experienced a change in financial circumstances due to the COVID-19 pandemic. For the three and nine months ended September 30, 2021, the estimated late payment charges and fees that were not billed were approximately $11 million and $46 million lower than the amounts that were approved to be collected pursuant to CECONY's rate plans, respectively, and $1 million and $3 million lower than the amounts that were approved to be collected pursuant to O&R's rate plans, respectively (see Note K). For the three and nine months ended September 30, 2020, the estimated late payment charges and fees that were not billed were approximately $17 million and $36 million lower than the amounts that were approved to be collected pursuant to CECONY's rate plans, respectively, and $1 million and $2 million lower than the amounts that were approved to be collected pursuant to O&R's rate plans, respectively (see Note K). In April 2021, CECONY filed a petition with the NYSPSC to timely establish a surcharge recovery mechanism to collect $52 million of late payment charges and fees, offset for related savings, for the year ended December 31, 2020 to begin in September 2021 and end in December 2022. The petition also requested a surcharge recovery or surcredit mechanism for any fee deferrals for 2021 and 2022 starting in January of the subsequent year over a twelve-month period, respectively. Public comments in response to the petition were filed in August 2021. CECONY resumed late payment charges for commercial and residential customers who have not experienced a change in financial circumstances due to the COVID-19 pandemic on September 3, 2021 and October 1, 2021, respectively. O&R resumed late payment charges for commercial and residential customers who have not experienced a change in financial circumstances due to the COVID-19 pandemic on October 1, 2021.

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The Utilities’ New York rate plans allow them to defer costs resulting from a change in legislation, regulation and related actions that have taken effect during the term of the rate plans once the costs exceed a specified threshold. The total reserve increases to the allowance for uncollectible accounts from January 1, 2020 through September 30, 2021 reflecting the impact of the COVID-19 pandemic for CECONY electric and gas operations and O&R electric and gas operations were $235 million and $7 million, respectively, and were deferred pursuant to the legislative, regulatory and related actions provisions of the rate plans as a result of the New York State on PAUSE and related executive orders, that have since been lifted, as described above. The Utilities’ New York rate plans also provide for an allowance for write-offs of customer accounts receivable balances. The above amounts deferred pursuant to the legislative, regulatory and related actions provisions were reduced by the amount that the actual write-offs of customer accounts receivable balances were below the allowance reflected in rates which differences were $12 million and $2 million for CECONY and O&R, respectively, from March 1, 2020 through September 30, 2021.

In June 2020, the NYSPSC directed CECONY to implement a summer cooling credit program to help mitigate the cost of staying home and operating air conditioning for health-vulnerable low-income customers due to the limited availability of public cooling facilities as a result of the COVID-19 social distancing measures. The $63.4 million cost of the program is being recovered over a five-year period that began January 2021.

In June 2020, the NYSPSC established a generic proceeding on the impacts of the COVID-19 pandemic and sought comment on a variety of COVID-19 related issues. In July 2020, the Utilities submitted joint comments with other large utilities in New York State that included a formal request to defer all COVID-19 related costs and for a surcharge mechanism to collect such deferrals based upon the individual utility's need. In January 2021, the NYSDPS provided guidance to New York utilities that no additional mechanisms are required because there are already established mechanisms for utility recovery of unexpected material expenses through rate plan change in legislation, regulation and related actions provisions of their respective rate plans and the filing of individual deferral petitions. The guidance further provided that utilities deferring COVID-19 related costs pursuant to the provisions that allow deferral of costs resulting from a change in legislation, regulation and related actions must comply with the provisions of their rate plans, be able to demonstrate the nexus between the changes in law or regulation and the specific revenue and expense items, and consider any offsetting cost savings due to the pandemic.

As of December 31, 2020, CECONY deferred, for New York City residential customers, $54.9 million of higher summer generation capacity supply costs. CECONY recovered such costs from customers as of October 31, 2021.

In April 2021, New York State passed a law that creates a program that allows eligible residential renters in New York State who require assistance with rent and utility bills to have up to twelve months of electric and gas utility bill arrears forgiven, provided that such arrears were accrued on or after March 13, 2020. The program will be administered by the State Office of Temporary Disability Assistance in coordination with the NYSDPS. Under the program, CECONY and O&R would qualify for a refundable tax credit for New York State gross-receipts tax equal to the amount of arrears waived by the Utilities in the year that the arrears are waived and certified by the NYSPSC.

In May 2021, CECONY and O&R, along with other large New York utilities, submitted joint comments to the NYSDPS' February 2021 report on New York State’s Energy Affordability Policy. The report recommends, among other things, that residential and commercial customers’ late payment fees and interest on deferred payment agreements be waived until two years after the expiration of the New York State moratorium on utility terminations (the moratorium will expire on December 21, 2021) and each utility develop an arrears management program to mitigate the financial burdens of the COVID-19 pandemic on New York households and that program costs be shared, perhaps equally, between shareholders and customers. The May 2021 joint comments stated that it is not necessary for the NYSPSC to adopt the report’s COVID-19 related recommendations because New York State already passed laws that address the issues in the report, as described above.

The Utilities’ rate plans have revenue decoupling mechanisms in their New York electric and gas businesses that largely reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC per month and accumulate the deferred balances semi-annually under CECONY's electric rate plan (January through June and July through December, respectively) and annually under CECONY's gas rate plan and O&R's New York electric and gas rate plans (January through December). Differences are accrued with interest each month for CECONY's and O&R's New York electric customers and after the annual deferral period ends for CECONY's and O&R's New York gas customers for refund to, or recovery from customers, as applicable. Generally, the refund to or recovery from customers begins August and February of each year over an ensuing six-month period for CECONY's electric customers and February of each year over an ensuing twelve-month period for CECONY's gas and O&R's New York electric and gas customers.

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New Jersey State Regulation

In March 2020, New Jersey Governor Murphy declared a Public Health Emergency and State of Emergency for the State of New Jersey. In June 2021, the Governor ended the emergency declaration. As a result of the emergency declaration, and due to economic conditions, the NJBPU and RECO have worked to mitigate the potential impact of the COVID-19 pandemic on RECO, its customers and other stakeholders. In March 2020, RECO began suspending late payment charges, terminations for non-payment, and no access fees during the COVID-19 pandemic. The suspension of these fees continued through July 31, 2021 and are not material.

In July 2020, the NJBPU authorized RECO and other New Jersey utilities to create a COVID-19-related regulatory asset by deferring prudently incurred incremental costs related to the COVID-19 pandemic beginning on March 9, 2020, and has extended such deferrals through December 31, 2022. RECO deferred net incremental COVID-19 related costs of $0.9 million through September 30, 2021.

Other Regulatory Matters

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, under its electric rate plan that was approved in January 2020, is amortizing its TCJA net benefits prior to January 1, 2019 allocable to its electric customers ($377 million) over a three-year period, the “protected” portion of its net regulatory liability for future income taxes related to certain accelerated tax depreciation benefits allocable to its electric customers ($1,663 million) over the remaining lives of the related assets and the remainder, or “unprotected” portion of the net regulatory liability allocable to its electric customers ($784 million) over a five-year period. CECONY, under its gas rate plan that was approved in January 2020, is amortizing its remaining TCJA net benefits prior to January 1, 2019 allocable to its gas customers ($63 million) over a two-year period, the protected portion of its net regulatory liability for future income taxes allocable to its gas customers ($725 million) over the remaining lives of the related assets and the unprotected portion of the net regulatory liability allocable to its gas customers ($107 million) over a five-year period.

CECONY's net benefits prior to October 1, 2018 allocable to the company’s steam customers ($15 million) are being 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 steam customers ($185 million) is being amortized over the remaining lives of the related assets (with the amortization period for the unprotected portion subject to review in its next steam rate proceeding).

O&R, under its current electric and gas rate plans, has reflected its TCJA net benefits in its electric and gas rates beginning as of January 1, 2019. Under the rate plans, O&R is amortizing its net benefits prior to January 1, 2019 ($22 million) over a three-year period, the protected portion of its net regulatory liability for future income taxes ($123 million) over the remaining lives of the related assets and the unprotected portion ($30 million) over a fifteen-year period. Pursuant to the October 2021 Joint Proposal, O&R will amortize the remaining unprotected portion of its net regulatory liability for future income taxes ($34 million) over a six-year period beginning January 1, 2022.

In January 2018, the NYSPSC issued an order initiating a focused operations audit of the Utilities’ financial accounting for income taxes. The audit is investigating the Utilities’ inadvertent understatement of a portion, the amount of which may be material, of their calculation of total federal income tax expense for ratemaking purposes. The understatement was related to the calculation of plant retirement-related cost of removal. As a result of such understatement, the Utilities accumulated significant income tax regulatory assets that were not reflected in O&R’s rate plans prior to 2014, CECONY’s electric and gas rate plans prior to 2015 and 2016, respectively, and is currently not reflected in CECONY’s steam rate plan. As part of the audit, the Utilities plan to pursue a private letter ruling from the Internal Revenue Service (IRS) that is expected to confirm, among other things, that in order to comply with IRS normalization rules, such understatement may not be corrected through a write-down of a portion of the regulatory asset and must be corrected through an increase in future years’ revenue requirements. The regulatory asset ($1,180 million and $26 million for CECONY and O&R, respectively, as of September 30, 2021 and $1,200 million and $29 million for CECONY and O&R, respectively, as of December 31, 2020) is netted against the future income tax regulatory liability on the Companies’ consolidated balance sheet. The Utilities are unable to estimate the amount or range of their possible loss, if any, related to this matter. At September 30, 2021, the Utilities have not accrued a liability related to this matter.

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In October 2020, the NYSPSC issued an order instituting a proceeding to consider requiring New York’s large, investor-owned utilities, including CECONY and O&R, to annually disclose what risks climate change poses to their companies, investors and customers going forward. The order notes that some holding companies, including Con Edison, already disclose climate change risks at the holding company level, but states that the NYSPSC believes that climate-related risk disclosures should be issued specific to the operating companies in New York, such as CECONY and O&R, and that such climate-related risk disclosures should be included annually with the utilities’ financial reports. In December 2020, CECONY and O&R, along with other large New York utilities, filed comments supporting climate change risk disclosures in annual reports filed with the NYSPSC and recommended the use of an industry-specific template.

In May 2020, the president of the United States issued the "Securing the United States Bulk-Power System" executive order. The executive order declares threats to the bulk-power system by foreign adversaries constitute a national emergency and prohibits the acquisition, importation, transfer or installation of certain bulk-power system electric equipment that is sourced from foreign adversaries. In January 2021, the president of the United States suspended the May 2020 executive order for 90 days. In April 2021, the executive order was reinstated (and expired shortly thereafter) and the Department of Energy (DOE) subsequently issued a request for information to assist the DOE in developing additional orders and/or regulations to secure the United States’ critical electric infrastructure. In September 2021, the Cybersecurity and Infrastructure Security Agency and the National Institute of Standards and Technology issued preliminary cybersecurity goals for critical infrastructure control systems, with final goals to be issued by September 2022. The Companies are unable to predict the impact on them of any orders or regulations that may be adopted regarding critical infrastructure.

In July 2021, the NYSPSC approved a settlement agreement among CECONY, O&R and the NYSDPS that fully resolves all issues and allegations that have been raised or could have been raised by the NYSPSC against CECONY and O&R with respect to: (1) the July 2018 rupture of a CECONY steam main located on Fifth Avenue and 21st Street in Manhattan (the “2018 Steam Incident”); (2) the July 2019 electric service interruptions to approximately 72,000 CECONY customers on the west side of Manhattan and to approximately 30,000 CECONY customers primarily in the Flatbush area of Brooklyn (the “2019 Manhattan and Brooklyn Outages”); (3) the August 2020 electric service interruptions to approximately 330,000 CECONY customers and approximately 200,000 O&R customers following Tropical Storm Isaias (the “Tropical Storm Isaias Outages”) and (4) the August 2020 electric service interruptions to approximately 190,000 customers resulting from faults at CECONY’s Rainey substation following Tropical Storm Isaias (the “Rainey Outages”). Pursuant to the settlement agreement, CECONY and O&R agreed to a total settlement amount of $75.1 million and $7.0 million, respectively. CECONY and O&R agreed to forgo recovery from customers of $25 million and $2.5 million, respectively, associated with the return on existing storm hardening assets beginning with the next rate plan for each utility (over a period of 35 years). CECONY and O&R also agreed to incur ongoing operations and maintenance costs of up to $15.8 million and $2.9 million, respectively, for, among other things, costs to maintain a certain level of contractor and vehicle storm emergency support and storm preparation audits. For CECONY, the settlement agreement includes previously incurred or accrued costs of $34.3 million, including negative revenue adjustments of $5 million for the Rainey Outages and $15 million for the 2019 Manhattan and Brooklyn Outages and $14.3 million in costs to reimburse customers for food and medicine spoilage and other previously incurred expenses related to Tropical Storm Isaias and the 2018 Steam Incident. For O&R, the settlement agreement includes previously incurred costs of $1.6 million to reimburse customers for food and medicine spoilage and other expenses related to the Tropical Storm Isaias Outages.

Additional information relating to the 2018 Steam Incident, 2019 Manhattan and Brooklyn Outages and Tropical Storm Isaias Outages follow.

2018 Steam Incident: In July 2018, the NYSPSC commenced an investigation into the rupture of a CECONY steam main located on Fifth Avenue and 21st Street in Manhattan. 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. As of June 30, 2021, with respect to the incident, the company incurred operating costs of $17 million for property damage, clean-up and other response costs and invested $9 million in capital and retirement costs. During the second quarter of 2020, the company accrued a $3 million liability related to this matter. As described above, in July 2021, CECONY entered into a settlement agreement that fully resolves all issues and allegations with respect to this matter.

2019 Manhattan and Brooklyn Outages: In July 2019, electric service was interrupted to approximately 72,000 CECONY customers on the west side of Manhattan. Also in July 2019, electric service was interrupted to approximately 30,000 CECONY customers primarily in the Flatbush area of Brooklyn. In November 2020, the NYSPSC issued an order in its proceedings investigating these July 2019 power outages ordering CECONY to

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show cause why the NYSPSC should not commence a review of the prudency of CECONY’s actions and/or omissions prior to, during, and after the July 2019 outages in Manhattan and Brooklyn, and pursue civil or administrative penalties in the amount of up to $24.8 million for CECONY’s alleged failure to comply with certain requirements. The order further indicated that should the NYSPSC confirm some or all of the apparent violations identified in the order or other orders issued by the NYSPSC in the future in connection with this proceeding, and should such confirmed violations be classified as findings of repeated violations of the Public Service Law or rules or regulations adopted pursuant thereto that demonstrate a failure of CECONY to continue to provide safe and adequate service, the NYSPSC would be authorized to commence a proceeding under Public Service Law Section 68(2) to revoke or modify CECONY’s certificate as it relates to its service territory or any portion thereof.

In December 2020, CECONY filed a response to the NYSPSC order demonstrating why the NYSPSC should not commence a penalty or prudence action against CECONY. CECONY stated that the NYSPSC order misapplied Section 25-a of the Public Service Law by ignoring the reasonable compliance standard under the statute and instead, was imposing a strict liability standard. For both outages, CECONY presented evidence that it either had complied or reasonably complied with NYSPSC requirements. With respect to the Manhattan outage, CECONY stated that a prudency proceeding was not justified because CECONY’s actions with respect to the Manhattan outage were reasonable based on the information the company had at the time. With respect to the Brooklyn outage, the company stated that the order failed to allege that improper company actions caused the outage. During 2019, CECONY recorded negative revenue adjustments associated with reliability performance provisions of $15 million in aggregate primarily related to these outages. As described above, in July 2021, CECONY entered into a settlement agreement that fully resolves all issues and allegations with respect to this matter.

Tropical Storm Isaias Outages: In August 2020, Tropical Storm Isaias caused significant damage to the Utilities’ electric distribution systems and interrupted service to approximately 330,000 CECONY electric customers and approximately 200,000 O&R electric customers. As of September 30, 2021, CECONY incurred costs for Tropical Storm Isaias of $175 million (including $84 million of operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan, $64 million of capital expenditures and $27 million (including $7.5 million for food and medicine spoilage claims) of operation and maintenance expenses). As of September 30, 2021, O&R incurred costs for Tropical Storm Isaias of $26.5 million (including $19.2 million of operation and maintenance expenses charged against a storm reserve pursuant to its New York electric rate plan, $5.7 million of capital expenditures and $1.6 million for food and medicine spoilage claims). As of September 30, 2021, RECO incurred costs for Tropical Storm Isaias of $11.3 million (including $7.5 million of operation and maintenance expenses charged against a storm reserve pursuant to its rate plan, $2.5 million of capital expenditures and $1.3 million for food and medicine spoilage claims). The Utilities’ electric rate plans provide for recovery of operating costs and capital expenditures under different provisions. The Utilities’ incremental operating costs attributable to storms are to be deferred for recovery as a regulatory asset under their electric rate plans, while capital expenditures, up to specified levels, are reflected in rates under their electric rate plans. The provisions of the Utilities’ New York electric rate plans that impose negative revenue adjustments for operating performance provide for exceptions for major storms and catastrophic events beyond the control of the companies, including natural disasters such as hurricanes and floods.

In November 2020, the NYSPSC issued an order in its proceedings investigating the New York utilities’ preparation for and response to Tropical Storm Isaias that ordered the Utilities to show cause why (i) civil penalties or appropriate injunctive relief should not be imposed against CECONY (in the amount of up to $102.3 million relating to 33 alleged violations) and against O&R (in the amount of up to $19 million relating to 38 alleged violations) to remedy such noncompliance, and (ii) a prudence proceeding should not be commenced against the Utilities for potentially imprudent expenditures of ratepayer funds related to the matter. The order stated that given the continuing nature of the investigation of this matter by the NYSDPS, the NYSPSC may amend the order to include any subsequently determined apparent violations identified by the NYSDPS. In addition, the order indicated that should the NYSPSC confirm some or all of the apparent violations identified in the order or other orders issued by the NYSPSC in the future in connection with this proceeding, and should such respective confirmed violations be classified as findings of repeated violations of the Public Service Law or rules or regulations adopted pursuant thereto that demonstrate a failure of CECONY and/or O&R to continue to provide safe and adequate service, the NYSPSC would be authorized to commence a proceeding under Public Service Law Section 68(2) to revoke or modify CECONY’s and/or O&R’s certificate as it relates to its service territory or any portion thereof.

In December 2020, CECONY and O&R filed responses to the NYSPSC order demonstrating why the NYSPSC should not commence penalty or prudence actions against them. The Utilities stated that the NYSPSC orders misapplied Section 25-a of the Public Service Law by ignoring the reasonable compliance standard under the statute and instead, was imposing a strict liability standard. CECONY and O&R also presented evidence that the order either misrepresented the applicable requirements or ignored that the Utilities were acting pursuant to

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practices approved by the NYSPSC. Finally, CECONY and O&R stated that there was no basis to commence a prudence proceeding because the Utilities acted reasonably based on the information available and the circumstances at the time. As described above, in July 2021, CECONY and O&R entered into a settlement agreement that fully resolves all issues and allegations with respect to this matter.

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Regulatory Assets and Liabilities

Regulatory assets and liabilities at September 30, 2021 and December 31, 2020 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Regulatory assets
Unrecognized pension and other postretirement costs	$2,527	$3,241	$2,394	$3,065
Environmental remediation costs	846	865	780	791
Pension and other postretirement benefits deferrals	438	315	382	272
Revenue taxes	385	356	369	342
COVID-19 pandemic deferrals	274	115	269	113
Deferred storm costs	277	195	155	83
Property tax reconciliation	245	241	245	239
MTA power reliability deferral	152	188	152	188
System peak reduction and energy efficiency programs	145	124	145	124
Deferred derivative losses - long term	136	120	124	111
Municipal infrastructure support costs	49	62	49	62
Brooklyn Queens demand management program	35	36	35	36
Meadowlands heater odorization project	30	32	30	32
Preferred stock redemption	20	21	20	21
Non-wire alternative projects	23	18	23	18
Unamortized loss on reacquired debt	17	21	15	19
Recoverable REV demonstration project costs	15	20	14	18
Gate station upgrade project	15	25	15	25
Other	274	200	257	186
Regulatory assets – noncurrent	5,903	6,195	5,473	5,745
Deferred derivative losses - short term	166	190	155	177
Recoverable energy costs	39	76	32	67
Regulatory assets – current	205	266	187	244
Total Regulatory Assets	$6,108	$6,461	$5,660	$5,989
Regulatory liabilities
Future income tax	$2,040	$2,207	$1,896	$2,062
Allowance for cost of removal less salvage	1,114	1,090	950	932
Net unbilled revenue deferrals	184	198	184	198
TCJA net benefits*	167	295	164	286
Net proceeds from sale of property	111	137	111	137
Deferred derivative gains - long term	110	5	101	4
Pension and other postretirement benefit deferrals	98	85	53	46
System benefit charge carrying charge	71	64	63	57
Property tax refunds	35	36	35	35
BQDM and REV Demo reconciliations	26	27	22	25
Sales and use tax refunds	18	16	17	16
Energy efficiency portfolio standard unencumbered funds	17	1	19	—
Earnings sharing - electric, gas and steam	13	15	10	10
Unrecognized other postretirement costs	12	11	—	—
Settlement of gas proceedings	11	21	11	21
Settlement of prudence proceeding	6	5	6	5
Workers' compensation	5	3	5	3
Other	341	297	294	257
Regulatory liabilities – noncurrent	4,379	4,513	3,941	4,094
Deferred derivative gains - short term	451	8	423	7
Refundable energy costs	31	28	5	4
Revenue decoupling mechanism	8	—	—	—
Regulatory liabilities – current	490	36	428	11
Total Regulatory Liabilities	$4,869	$4,549	$4,369	$4,105

* See "Other Regulatory Matters," above.

The recognition of the return on regulatory assets is determined by the Utilities’ rate plans or orders issued by state regulators. In general, the Utilities receive or are being credited with a return at the Other Customer-Provided

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Capital rate for regulatory assets that have not been included in rate base, and receive or are being credited with a return at the pre-tax weighted average cost of capital once the asset is included in rate base. Similarly, the Utilities pay to or credit customers with a return at the Other Customer-Provided Capital rate for regulatory liabilities that have not been included in rate base, and pay to or credit customers with a return at the pre-tax weighted average cost of capital once the liability is included in rate base. The Other Customer-Provided Capital rate for the nine months ended September 30, 2021 and 2020 was 1.80 percent and 2.65 percent, respectively.

In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made ($2,027 million and $1,696 million for Con Edison, and $1,817 million and $1,509 million for CECONY at September 30, 2021 and December 31, 2020, respectively). Regulatory assets of RECO for which a cash outflow has been made ($24 million and $31 million at September 30, 2021 and December 31, 2020, respectively) are not receiving or being credited with a return. RECO recovers regulatory assets over a period of up to four years or until they are addressed in its next base rate case in accordance with the rate provisions approved by the New Jersey Board of Public Utilities. Regulatory liabilities are treated in a consistent manner.

Regulatory assets that represent future financial obligations and were deferred in accordance with the Utilities’ rate plans or orders issued by state regulators do not earn a return until such time as a cash outlay has been made. Regulatory liabilities are treated in a consistent manner. At September 30, 2021 and December 31, 2020, regulatory assets for Con Edison and CECONY that did not earn a return consisted of the following items:

Regulatory Assets Not Earning a Return*

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Unrecognized pension and other postretirement costs	$2,527	$3,241	$2,394	$3,065
Environmental remediation costs	832	855	765	781
Revenue taxes	364	336	349	323
Deferred derivative losses - long term	136	120	124	111
Other	56	24	56	24
Deferred derivative losses - current	166	190	155	177
Total	$4,081	$4,766	$3,843	$4,481

*This table includes regulatory assets not earning a return for which no cash outlay has been made.

The recovery periods for regulatory assets for which a cash outflow has not been made and that do not earn a return have not yet been determined, except as noted below, and are expected to be determined pursuant to the Utilities’ future rate plans to be filed or orders issued by the state regulators in connection therewith.

The Utilities recover unrecognized pension and other postretirement costs over 10 years pursuant to NYSPSC policy.

The deferral for revenue taxes represents the New York State metropolitan transportation business tax surcharge on the cumulative temporary differences between the book and tax basis of assets and liabilities of the Utilities, as well as the difference between taxes collected and paid by the Utilities to fund mass transportation. The Utilities recover the majority of the revenue taxes over the remaining book lives of the electric and gas plant assets, as well as the steam plant assets for CECONY.

The Utilities recover deferred derivative losses – current within one year, and noncurrent generally within three years.

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Note C – Capitalization

In February 2021, a subsidiary of the Clean Energy Businesses borrowed $250 million at a variable-rate, due 2028, secured by equity interests in four of the company’s solar electric production projects, the interest rate for which was swapped to a fixed rate of 3.39 percent.

In February 2021, a subsidiary of the Clean Energy Businesses entered into an agreement with a tax equity investor for the financing of a portfolio of three of the Clean Energy Businesses’ solar electric production projects (CED Nevada Virginia). Under the financing, the tax equity investor acquired a noncontrolling interest in the portfolio and will receive a percentage of earnings, tax attributes and cash flows. As of September 30, 2021, the tax equity investor fully funded its $263 million financing obligation. The Clean Energy Businesses will continue to consolidate this entity and will report the noncontrolling tax equity investor’s interest in the tax equity arrangement. See Note P.

In March 2021, a subsidiary of the Clean Energy Businesses agreed to issue $229 million aggregate principal amount of 3.77 percent senior notes, due 2046, secured by equity interests in CED Nevada Virginia, all of which had been issued at September 30, 2021.

During the first quarter of 2021, Con Edison optionally prepaid the remaining $675 million outstanding under a February 2019 term loan prior to its maturity in June 2021.

In May 2021, Con Edison redeemed at maturity $500 million of 2.00 percent 5-year debentures.

In June 2021, CECONY redeemed at maturity $640 million of floating rate 3-year debentures.

In June 2021, CECONY issued $750 million aggregate principal amount of 2.40 percent debentures, due 2031 and $750 million aggregate principal amount of 3.60 percent debentures, due 2061.

In June 2021, Con Edison issued 10,100,000 shares of its common stock resulting in net proceeds of approximately $775 million, after issuance expenses.

In June 2021, as part of the Clean Energy Businesses’ sale of a renewable electric production project, $104 million of 4.52 percent senior notes, due 2032 and $37 million of floating rate loans, due 2024 and loan-related interest rate swaps were assumed by the buyer pursuant to the sale agreement. See Notes N and R.

In September 2021, O&R agreed to issue in December 2021 $45 million aggregate principal amount of 2.31 percent debentures, due 2031 and $30 million aggregate principal amount of 3.17 percent debentures, due 2051.

The carrying amounts and fair values of long-term debt at September 30, 2021 and December 31, 2020 were:

(Millions of Dollars)	2021		2020
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$22,280	$25,655	$22,349	$26,808
CECONY	$17,637	$20,774	$16,789	$20,974

(a)Amounts shown are net of unamortized debt expense and unamortized debt discount of $221 million and $188 million for Con Edison and CECONY, respectively, as of September 30, 2021 and $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020.

The fair values of the Companies' long-term debt have been estimated primarily using available market information and at September 30, 2021 are classified as Level 2 liabilities (see Note O).

Note D – Short-Term Borrowing

At September 30, 2021, Con Edison had $1,036 million of commercial paper outstanding of which $942 million was outstanding under CECONY’s program. The weighted average interest rate at September 30, 2021 was 0.1 percent for both Con Edison and CECONY. At December 31, 2020, Con Edison had $1,705 million of commercial paper outstanding of which $1,660 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2020 was 0.3 percent for both Con Edison and CECONY.

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At September 30, 2021 and December 31, 2020, 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 September 30, 2021 and December 31, 2020.

In August 2021, a subsidiary of the Clean Energy Businesses prepaid in full $249 million of borrowings outstanding under, and terminated, a $613 million variable-rate construction loan facility that was secured by and used to fund construction costs for CED Nevada Virginia. At December 31, 2020, the banks’ commitments under the construction loan facility were $613 million, and $165 million of borrowings were outstanding under the construction loan facility.

In April 2021, Con Edison entered into a credit agreement (April 2021 Credit Agreement) under which banks were committed until May 18, 2021, subject to certain conditions, to provide to Con Edison a $500 million variable-rate 364-day term loan. In May 2021, Con Edison borrowed $500 million under the April 2021 Credit Agreement to repay in full all of Con Edison’s outstanding 2.00 percent debentures, Series 2016 A, that matured on May 15, 2021. In July 2021, Con Edison prepaid in full the $500 million borrowing under the April 2021 Credit Agreement with a portion of the cash proceeds received from the substantial completion of the sale of Stagecoach. See Note R.

Note E – Pension Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit cost for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost – including administrative expenses	$85	$73	$80	$69
Interest cost on projected benefit obligation	118	137	111	129
Expected return on plan assets	(274)	(258)	(260)	(245)
Recognition of net actuarial loss	197	175	187	165
Recognition of prior service credit	(4)	(4)	(5)	(5)
TOTAL PERIODIC BENEFIT COST	$122	$123	$113	$113
Cost capitalized	(41)	(34)	(39)	(32)
Reconciliation to rate level	(54)	(62)	(52)	(59)
Total expense recognized	$27	$27	$22	$22

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost – including administrative expenses	$257	$220	$241	$206
Interest cost on projected benefit obligation	353	412	332	387
Expected return on plan assets	(822)	(775)	(779)	(735)
Recognition of net actuarial loss	590	524	559	496
Recognition of prior service credit	(12)	(12)	(15)	(15)
TOTAL PERIODIC BENEFIT COST	$366	$369	$338	$339
Cost capitalized	(120)	(98)	(113)	(93)
Reconciliation to rate level	(165)	(188)	(158)	(179)
Total expense recognized	$81	$83	$67	$67

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.

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Expected Contributions

Based on estimates as of September 30, 2021, the Companies expect to make contributions to the pension plans during 2021 of $467 million (of which $429 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 nine months of 2021, the Companies contributed $465 million to the pension plans, $428 million of which was contributed by CECONY. CECONY also contributed $22 million to the external

trust for its non-qualified supplemental plan.

Note F – Other Postretirement Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic other postretirement benefit cost/(credit) for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost - including administrative expenses	$2	$5	$1	$4
Interest cost on projected other postretirement benefit obligation	7	9	6	8
Expected return on plan assets	(17)	(16)	(14)	(14)
Recognition of net actuarial loss	4	3	3	3
Recognition of prior service credit	—	(1)	—	—
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(4)	$—	$(4)	$1
Cost capitalized	(3)	(2)	(3)	(2)
Reconciliation to rate level	7	2	6	—
Total credit recognized	$—	$—	$(1)	$(1)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost - including administrative expenses	$15	$16	$11	$12
Interest cost on projected other postretirement benefit obligation	23	28	19	23
Expected return on plan assets	(51)	(49)	(41)	(41)
Recognition of net actuarial loss	17	34	13	32
Recognition of prior service credit	(2)	(3)	(1)	(1)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$2	$26	$1	$25
Cost capitalized	(9)	(7)	(7)	(5)
Reconciliation to rate level	7	(19)	2	(24)
Total credit recognized	$—	$—	$(4)	$(4)

For information about the presentation of the components of other postretirement benefit costs, see Note E.

Contributions

During the first nine months of 2021, the Companies contributed $2 million (all of which was made by CECONY) to the other postretirement benefit plans. The Companies' policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

Note G – Environmental Matters

Superfund Sites

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

The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances

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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 September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Accrued Liabilities:
Manufactured gas plant sites	$737	$752	$662	$676
Other Superfund Sites	104	105	103	104
Total	$841	$857	$765	$780
Regulatory assets	$846	$865	$780	$791

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 and nine months ended September 30, 2021 and 2020 were as follows: 

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Remediation costs incurred	$7	$8	$7	$8

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Remediation costs incurred	$21	$17	$20	$16

Insurance and other third-party recoveries received by Con Edison or CECONY were immaterial for the three and nine months ended September 30, 2021 and 2020.

In 2020, 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 $2.7 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.

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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 September 30, 2021, 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 or liabilities for the Companies at September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$68	$72	$65	$68
Regulatory liability – workers’ compensation	$5	$3	$5	$3

Note H – Other Material Contingencies

Manhattan Explosion and Fire

On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th 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 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. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At September 30, 2021 and December 31, 2020, the company had accrued its estimated liability for the suits of $40 million and an insurance receivable in the same amount.

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Other Contingencies

For additional contingencies, see "Other Regulatory Matters" in Note B, Note G 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 and its subsidiaries under these agreements totaled $2,210 million and $2,042 million at September 30, 2021 and December 31, 2020, respectively.

A summary, by type and term, of amounts guaranteed by Con Edison and its subsidiaries under these agreements at September 30, 2021 is as follows:

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years	Total
	(Millions of Dollars)
Con Edison Transmission	$547	$—	$—	$547
Energy transactions	475	33	323	831
Renewable electric production projects	320	64	378	762
Other	70	—	—	70
Total	$1,412	$97	$701	$2,210

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 owns a 45.7 percent interest in NY Transco. In April 2019, the New York Independent System Operator (NYISO) selected a transmission project that was jointly proposed by National Grid and NY Transco. The siting, construction and operation of the project will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO indicated it will work with the developers to enter into agreements for the development and operation of the projects, including a schedule for entry into service by December 2023. Guarantee amount shown includes the maximum possible required amount of CET Electric’s contributions for this project as calculated based on the assumptions that the project is completed at 175 percent of its estimated costs and NY Transco does not use any debt financing for the project. Guarantee amount shown also includes a $7 million guarantee from Con Edison Transmission on behalf of a subsidiary of CET Gas related to the completion of the sale of Stagecoach. See "Investments" in Note A and Note R.

Energy Transactions — Con Edison and the Clean Energy Businesses guarantee payments on behalf of their subsidiaries 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 and the Clean Energy Businesses 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 the operation of solar energy facilities and energy service projects of the Clean Energy Businesses.

Note I – Leases

Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Operating lease cost	$22	$21	$16	$16
Operating lease cash flows	$10	$10	$6	$6

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	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Operating lease cost	$65	$63	$49	$48
Operating lease cash flows	$26	$27	$15	$13

As of September 30, 2021, assets recorded as finance leases were $2 million for Con Edison and $1 million for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $2 million, respectively. As of December 31, 2020, assets recorded as finance leases were $3 million for Con Edison and $2 million for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively.

For the three and nine months ended September 30, 2021 and 2020, finance lease costs and cash flows for Con Edison and CECONY were immaterial.

Right-of-use assets obtained in exchange for operating lease obligations for Con Edison and CECONY were $15 million and $5 million, respectively, for the three months ended September 30, 2021 and $32 million and $7 million, respectively for the nine months ended September 30, 2021. Right-of-use assets obtained in exchange for operating lease obligations for Con Edison and CECONY were $8 million and $2 million, respectively, for the three months ended September 30, 2020 and $13 million and $3 million, respectively for the nine months ended September 30, 2020.

Other information related to leases for Con Edison and CECONY at September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
	2021	2020	2021	2020
Weighted Average Remaining Lease Term:
Operating leases	18.5 years	19.1 years	12.4 years	13.0 years
Finance leases	7.1 years	7.3 years	3.3 years	4.0 years
Weighted Average Discount Rate:
Operating leases	4.3%	4.3%	3.6%	3.6%
Finance leases	1.8%	1.8%	1.2%	1.3%

Future minimum lease payments under non-cancellable leases at September 30, 2021 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending September 30,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2022	$82	$1	$59	$1
2023	76	—	58	—
2024	75	—	57	—
2025	76	—	58	—
2026	75	—	58	—
All years thereafter	937	1	446	—
Total future minimum lease payments	$1,321	$2	$736	$1
Less: imputed interest	(452)	—	(144)	—
Total	$869	$2	$592	$1
Reported as of September 30, 2021
Operating lease liabilities (current)	$113	$—	$85	$—
Operating lease liabilities (noncurrent)	756	—	507	—
Other current liabilities	—	1	—	—
Other noncurrent liabilities	—	1	—	1
Total	$869	$2	$592	$1

At September 30, 2021, the Companies did not have material obligations under operating or finance leases that had not yet commenced.

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The Companies are lessors under certain leases whereby the Companies own real estate and distribution poles and lease portions of them to others. Revenue under such leases was immaterial for Con Edison and CECONY for the three and nine months ended September 30, 2021 and 2020.

Note J – Income Tax

Con Edison’s income tax expense increased to $127 million for the three months ended September 30, 2021 from $119 million for the three months ended September 30, 2020. The increase in income tax expense is primarily due to lower income attributable to non-controlling interests, offset in part by lower income before income tax expense, lower state income taxes, an increase in the amortization of excess deferred federal income taxes due to the TCJA and a higher favorable tax adjustment for the prior year tax return primarily due to an increase in the general business tax credit compared with last year.

CECONY’s income tax expense decreased to $90 million for the three months ended September 30, 2021 from $97 million for the three months ended September 30, 2020. The decrease in income tax expense is primarily due to an increase in the amortization of excess deferred federal income taxes due to the TCJA and a higher favorable tax adjustment for the prior year tax return primarily due to an increase in the general business tax credit compared with last year, offset in part by higher income before income tax expense and lower flow-through tax benefits in 2021 for plant-related items.

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 September 30, 2021 and 2020 is as follows:

	Con Edison				CECONY
(% of Pre-tax income)	2021		2020		2021		2020
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income tax, net of federal income tax benefit	5		6		5		5
Amortization of excess deferred federal income taxes	(7)		(7)		(8)		(8)
Taxes attributable to non-controlling interests	4		(1)		—		—
Cost of removal	1		1		1		2
Other plant-related items	(1)		(1)		(1)		(1)
Renewable energy credits	(1)		(1)		—		—
Injuries and damages reserve	—		—		1		—
Prior period federal income tax return adjustments	(1)		—		(1)		—
Other	—		1		—		—
Effective tax rate	21	%	19	%	18	%	19	%

Con Edison’s income tax expense increased to $194 million for the nine months ended September 30, 2021 from $183 million for the nine months ended September 30, 2020. The increase in income tax expense is primarily due to lower income attributable to non-controlling interests, offset in part by lower income before income tax expense, lower state income taxes, an increase in the amortization of excess deferred federal income taxes due to the TCJA and a higher favorable tax adjustment for the prior year tax return primarily due to an increase in the general business tax credit compared with last year.

CECONY’s income tax expense decreased to $188 million for the nine months ended September 30, 2021 from $199 million for the nine months ended September 30, 2020. The decrease in income tax expense is primarily due to an increase in the amortization of excess deferred federal income taxes due to the TCJA, a higher favorable tax adjustment for the prior year tax return primarily due to an increase in the general business tax credit compared with last year, the absence of the amortization of excess deferred state income taxes in 2021, offset in part by higher income before income tax expense and lower flow-through tax benefits in 2021 for plant-related items.

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 nine months ended September 30, 2021 and 2020 is as follows:

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	Con Edison				CECONY
(% of Pre-tax income)	2021		2020		2021		2020
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income tax, net of federal income tax benefit	5		5		5		5
Amortization of excess deferred federal income taxes	(11)		(10)		(11)		(10)
Taxes attributable to non-controlling interests	3		(1)		—		—
Cost of removal	2		2		2		2
Other plant-related items	(1)		(1)		(1)		(2)
Renewable energy credits	(2)		(2)		—		—
Other	(1)		—		—		1
Effective tax rate	16	%	14	%	16	%	17	%

In response to the economic impacts of the COVID-19 pandemic, the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) was signed into law on March 27, 2020. The CARES Act provides relief to corporate taxpayers by permitting a five-year carryback of net operating losses (NOLs) for tax years 2018, 2019 and 2020, temporarily removing the 80 percent limitation when applying the NOLs to carryback years, increasing the 30 percent limitation on interest deductibility to 50 percent of adjusted taxable income for tax years 2019 and 2020, and provides for certain employee retention tax credits and refunds for eligible employers.

Under the CARES Act, Con Edison carried back its $29 million NOL from tax year 2018 to tax year 2013 generating a $2.5 million net tax refund for which a tax receivable was established in 2020. In addition, Con Edison recognized a discrete income tax benefit of $4 million in 2020, due to the higher federal statutory tax rate in 2013. The 2018 federal NOL was recorded at 21 percent and will be carried back to tax year 2013, which had a 35 percent federal statutory tax rate. This tax benefit was primarily recognized at the Clean Energy Businesses.

Pursuant to CECONY’s electric rate plan that went into effect in January 2020, the deferral of its net benefits for its electric service ceased and is included in rates. Additionally, the unprotected excess deferred federal income taxes for its electric and gas services is being amortized over a five-year period, which decreased the income tax expense for the nine months ended September 30, 2021 and 2020. See “Other Regulatory Matters” in Note B.

In April 2021, New York State passed a law that increased the corporate franchise tax rate on business income from 6.5% to 7.25%, retroactive to January 1, 2021, for taxpayers with taxable income greater than $5 million. The law also reinstated the business capital tax at 0.1875%, not to exceed an annual maximum tax liability of $5 million per taxpayer. New York State requires a corporate franchise taxpayer to calculate and pay the highest amount of tax under the three alternative methods: a tax on business income; a tax on business capital; or a fixed dollar minimum. The provisions to increase the corporate franchise tax rate and reinstate a business capital tax are scheduled to expire after 2023 and are not expected to have a material impact on the Companies’ financial position, results of operations or liquidity.

Uncertain Tax Positions

At September 30, 2021, the estimated liability for uncertain tax positions for Con Edison was $17 million ($6 million for CECONY). Con Edison reasonably expects to resolve within the next twelve months approximately $3 million of various federal and state uncertainties due to the expected completion of ongoing tax examinations, of which the entire amount, if recognized, would reduce Con Edison's effective tax rate. The amount related to CECONY is $1 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 $17 million ($16 million, net of federal taxes) with $6 million attributable to CECONY.

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. For the nine months ended September 30, 2021, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At September 30, 2021 and December 31, 2020, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

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Note K – Revenue Recognition

The following table presents, for the three and nine months ended September 30, 2021 and 2020, revenue from contracts with customers as defined in Accounting Standards Codification 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 September 30, 2021			For the Three Months Ended September 30, 2020
(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	$2,776	$(46)	$2,730	$2,594	$(32)	$2,562
Gas	305	2	307	248	11	259
Steam	52	3	55	50	1	51
Total CECONY	$3,133	$(41)	$3,092	$2,892	$(20)	$2,872
O&R
Electric	229	(6)	223	210	(2)	208
Gas	32	2	34	27	3	30
Total O&R	$261	$(4)	$257	$237	$1	$238
Clean Energy Businesses
Renewables	199	—	199	194	—	194
Energy services	65	—	65	14	—	14
Other	—	—	—	—	14	14
Total Clean Energy Businesses	$264	$0	$264	$208	$14	$222
Con Edison Transmission	1	—	1	1	—	1
Other (b)	—	(1)	(1)	—	—	—
Total Con Edison	$3,659	$(46)	$3,613	$3,338	$(5)	$3,333

(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)    Parent company and consolidation adjustments.

	For the Nine Months Ended September 30, 2021			For the Nine Months Ended September 30, 2020
(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	$6,695	$(34)	$6,661	$6,108	$70	$6,178
Gas	1,699	31	1,730	1,480	29	1,509
Steam	383	10	393	375	10	385
Total CECONY	$8,777	$7	$8,784	$7,963	$109	$8,072
O&R
Electric	535	(13)	522	478	5	483
Gas	184	(7)	177	156	8	164
Total O&R	$719	$(20)	$699	$634	$13	$647
Clean Energy Businesses
Renewables	545	—	545	487	—	487
Energy services	168	—	168	36	—	36
Other	—	66	66	—	43	43
Total Clean Energy Businesses	$713	$66	$779	$523	$43	$566
Con Edison Transmission	3	—	3	3	—	3
Other (b)	—	(4)	(4)	—	(2)	(2)
Total Con Edison	$10,212	$49	$10,261	$9,123	$163	$9,286

(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)    Parent company and consolidation adjustments.

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	2021			2020
(Millions of Dollars)	Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)
Beginning balance as of January 1,	$11	$41		$29	$17
Additions (c)	174	—		74	31
Subtractions (c)	127	31	(d)	90	4	(d)
Ending balance as of September 30,	$58	$10		$13	$44

(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, $31 million and $4 million were included in the balances as of January 1, 2021 and 2020, respectively.

As of September 30, 2021, the aggregate amount of the remaining fixed performance obligations of the Clean Energy Businesses under contracts with customers for energy services is $187 million, of which $148 million will be recognized within the next two years, and the remaining $39 million will be recognized pursuant to long-term service and maintenance agreements.

In March 2020, the Utilities began suspending new late payment charges and certain other fees for all customers. For the three months ended September 30, 2021, the estimated late payment charges and fees that were not billed by Con Edison and CECONY were approximately $12 million and $11 million lower than the amounts that were approved to be collected pursuant to the Utilities’ rate plans, respectively. For the nine months ended September 30, 2021, the estimated late payment charges and fees that were not billed by Con Edison and CECONY were approximately $49 million and $46 million lower than the amounts that were approved to be collected pursuant to the Utilities’ rate plans, respectively. For the three months ended September 30, 2020, the estimated late payment charges and fees that were not billed by Con Edison and CECONY were approximately $18 million and $17 million lower than the amounts that were approved to be collected pursuant to the Utilities’ rate plans, respectively. For the nine months ended September 30, 2020, the estimated late payment charges and fees that were not billed by Con Edison and CECONY were approximately $38 million and $36 million lower than the amounts that were approved to be collected pursuant to the Utilities’ rate plans, respectively. The Utilities also began providing payment extensions for all customers that were scheduled to be disconnected prior to the start of the COVID-19 pandemic. In April 2021, CECONY filed a petition with the NYSPSC to timely establish a surcharge recovery mechanism for $52 million of late payment charges and fees, offset for related savings, for the year ended December 31, 2020 to begin in September 2021 and end in December 2022. The petition also requests a surcharge recovery or surcredit mechanism for any fee deferrals for 2021 and 2022 starting in January of the subsequent year over a twelve-month period, respectively. See "COVID-19 Regulatory Matters" in Note B.

Note L – Current Expected Credit Losses

In January 2020, the Companies adopted Accounting Standards Update (ASU) 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments”.

Allowance for Uncollectible Accounts

The Utilities’ “Account receivable – customers” balance consists of utility bills due (bills are generally due the month following billing) from customers who have energy delivered, generated, or services provided by the Utilities. The balance also reflects the Utilities’ purchase of receivables from energy service companies to support the retail choice programs.

“Other receivables” balance generally reflects costs billed by the Utilities for goods and services provided to external parties, such as accommodation work for private parties and certain governmental entities, real estate rental and pole attachments. The Clean Energy Businesses’ other receivables balance includes bills related to the sale of energy from renewable electric production projects.

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The Clean Energy Businesses’ customer accounts receivable balance generally reflects the management of energy supply assets, energy-efficiency services to government and commercial customers, and the engineering, procurement, and construction services of renewable energy projects. The Clean Energy Businesses calculate an allowance for uncollectible accounts related to their energy services customers based on an aging and customer-specific analysis. The amount of such reserves was not material at September 30, 2021 or December 31, 2020.

The Companies develop expected loss estimates using past events data and consider current conditions and future reasonable and supportable forecasts. Changes to the Utilities’ reserve balances that result in write-offs of customer accounts receivable balances above existing rate allowances are not reflected in rates during the term of the current rate plans. For the Utilities’ customer accounts receivable allowance for uncollectible accounts, past events considered include write-offs relative to customer accounts receivable; current conditions include macro-and micro-economic conditions related to trends in the local economy and bankruptcy rates and aged customer accounts receivable balances, among other factors; and forecasts about the future include assumptions related to the level of write-offs and recoveries. Generally, the Utilities write off customer accounts receivable as uncollectible 90 days after the account is turned off for non-payment, or the account is closed during the collection process. See "COVID-19 Regulatory Matters" in Note B.

Other receivables allowance for uncollectible accounts is calculated based on a historical average of collections relative to total other receivables, including current receivables. Current macro- and micro-economic conditions are also considered when calculating the current reserve. Probable outcomes of pending litigation, whether favorable or unfavorable to the Companies, are also included in the consideration.

Starting in 2020, the potential economic impact of the COVID-19 pandemic was also considered in forward-looking projections related to write-off and recovery rates and resulted in increases to the allowance for uncollectible accounts. The increases to the allowance for uncollectible customer accounts for Con Edison and CECONY were $38 million for the three months ended September 30, 2021 and $165 million and $162 million, respectively, for the nine months ended September 30, 2021. The increases to the allowance for uncollectible customer accounts for Con Edison and CECONY were $31 million and $30 million, respectively, for the three months ended September 30, 2020 and $48 million and $46 million, respectively, for the nine months ended September 30, 2020.

Customer accounts receivable and the associated allowance for uncollectible accounts are included in the line “Accounts receivable – customers” on the Companies’ consolidated balance sheets. Other receivables and the associated allowance for uncollectible accounts are included in “Other receivables” on the consolidated balance sheets.

The table below presents a rollforward by major portfolio segment type for the three and nine months ended September 30, 2021 and 2020:

	For the Three Months Ended September 30,
	Con Edison				CECONY
	Accounts receivable - customers		Other receivables		Accounts receivable - customers		Other receivables
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
Allowance for credit losses
Beginning Balance at July 1,	$275	$87	$7	$5	$262	$81	$4	$3
Recoveries	3	2	—	—	3	2	—	—
Write-offs	(24)	(4)	—	—	(23)	(3)	—	—
Reserve adjustments	59	33	—	1	58	31	1	1
Ending Balance September 30,	$313	$118	$7	$6	$300	$111	$5	$4

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	For the Nine Months Ended September 30,
	Con Edison				CECONY
	Accounts receivable - customers		Other receivables		Accounts receivable - customers		Other receivables
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
Allowance for credit losses
Beginning Balance at January 1,	$148	$70	$7	$4	$138	$65	$4	$3
Recoveries	9	6	—	—	8	6	—	—
Write-offs	(66)	(37)	(1)	(1)	(62)	(35)	—	—
Reserve adjustments	222	79	1	3	216	75	1	1
Ending Balance September 30,	$313	$118	$7	$6	$300	$111	$5	$4

Note M – 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 and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Operating revenues		Inter-segment revenues		Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
CECONY
Electric	$2,730	$2,562	$5	$4	$324	$305	$834	$813
Gas	307	259	2	2	82	74	(48)	(34)
Steam	55	51	18	18	23	22	(58)	(57)
Consolidation adjustments	—	—	(25)	(24)	—	—	—	—
Total CECONY	$3,092	$2,872	$—	$—	$429	$401	$728	$722
O&R
Electric	$223	$208	$—	$—	$18	$17	$55	$58
Gas	34	30	—	—	6	6	(8)	(9)
Total O&R	$257	$238	$—	$—	$24	$23	$47	$49
Clean Energy Businesses	$264	$222	$—	$—	$58	$58	$79	$92
Con Edison Transmission	1	1	—	—	—	—	(2)	(2)
Other (a)	(1)	—	—	—	1	—	(2)	(1)
Total Con Edison	$3,613	$3,333	$—	$—	$512	$482	$850	$860

(a) Parent company and consolidation adjustments. Other does not represent a business segment.

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	For the Nine Months Ended September 30,
	Operating revenues		Inter-segment revenues		Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
CECONY
Electric	$6,661	$6,178	$14	$13	$959	$904	$1,337	$1,413
Gas	1,730	1,509	6	5	239	216	490	440
Steam	393	385	55	56	69	67	9	1
Consolidation adjustments	—	—	(75)	(74)	—	—	—	—
Total CECONY	$8,784	$8,072	$—	$—	$1,267	$1,187	$1,836	$1,854
O&R
Electric	$522	$483	$—	$—	$52	$48	$78	$86
Gas	177	164	—	—	19	19	30	28
Total O&R	$699	$647	$—	$—	$71	$67	$108	$114
Clean Energy Businesses	$779	$566	$—	$—	$172	$173	$196	$188
Con Edison Transmission	3	3	—	—	1	1	(7)	(6)
Other (a)	(4)	(2)	—	—	—	—	(4)	(3)
Total Con Edison	$10,261	$9,286	$—	$—	$1,511	$1,428	$2,129	$2,147

(a) Parent company and consolidation adjustments. Other does not represent a business segment.

Note N – 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. These are economic hedges, for which the Utilities and the Clean Energy Business do not elect hedge accounting. The Clean Energy Businesses use interest rate swaps to manage the risks associated with interest rates related to outstanding and expected future debt issuances and borrowings. Derivatives are recognized on the consolidated balance sheet at fair value (see Note O), 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.

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The fair values of the Companies’ derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at September 30, 2021 and December 31, 2020 were:

(Millions of Dollars)	2021				2020
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	$652	$(375)	$277	(b)	$44	$14	$58	(b)
Noncurrent	140	(15)	125	(c)	22	35	57
Total fair value of derivative assets	$792	$(390)	$402		$66	$49	$115
Fair value of derivative liabilities
Current	$(428)	$265	$(163)	(c)	$(225)	$(13)	$(238)	(d)
Noncurrent	(183)	17	(166)	(c)	(207)	(33)	(240)	(d)
Total fair value of derivative liabilities	$(611)	$282	$(329)		$(432)	$(46)	$(478)
Net fair value derivative assets/(liabilities)	$181	($108)	$73		$(366)	$3	$(363)
CECONY
Fair value of derivative assets
Current	$407	$(183)	$224	(b)	$20	$(12)	$8	(b)
Noncurrent	114	(28)	86		16	(8)	8
Total fair value of derivative assets	$521	$(211)	$310		$36	$(20)	$16
Fair value of derivative liabilities
Current	$(158)	$44	$(114)		$(174)	$11	$(163)
Noncurrent	(125)	28	(97)		(114)	9	(105)
Total fair value of derivative liabilities	$(283)	$72	$(211)		$(288)	$20	$(268)
Net fair value derivative assets/(liabilities)	$238	$(139)	$99		$(252)	$—	$(252)

(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 September 30, 2021, immaterial amounts of margin deposits for Con Edison and CECONY were classified as derivative assets on the consolidated balance sheet, but not included in the table. At December 31, 2020, margin deposits for Con Edison and CECONY of $3 million 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)Includes amounts for interest rate swaps of $5 million in noncurrent assets, $(26) million in current liabilities and $(39) million in noncurrent liabilities. At September 30, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,046 million. The expiration dates of the swaps range from 2025-2041. In June 2021, as part of the Clean Energy Businesses' sale of a renewable electric project, interest rate swaps terminating in 2024 were assumed by the buyer.

(d)Includes amounts for interest rate swaps of $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps ranged from 2024-2041.

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 regulatory 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 gas purchased for resale and non-utility revenue in the reporting period in which they occur. The Clean Energy Businesses record changes in the fair value of their interest rate swaps in other interest expense at the end of each reporting period. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices and interest rates.

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The following table presents the realized and unrealized gains or losses on derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2021 and 2020:

		For the Three Months Ended September 30,
		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2021	2020	2021	2020
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$296	$26	$279	$24
Noncurrent	Deferred derivative gains	70	17	66	16
Total deferred gains/(losses)		$366	$43	$345	$40
Current	Deferred derivative losses	$(4)	$(9)	$(3)	$(11)
Current	Recoverable energy costs	17	(23)	13	(19)
Noncurrent	Deferred derivative losses	(61)	(15)	(55)	(12)
Total deferred gains/(losses)		($48)	$(47)	$(45)	$(42)
Net deferred gains/(losses)		$318	$(4)	$300	$(2)
	Income Statement Location
Pre-tax gains/(losses) recognized in income
	Gas purchased for resale	$2	$—	$—	$—
	Non-utility revenue	(23)	(2)	—	—
	Other operations and maintenance expense	1	—	1	—
	Other interest expense	11	7	—	—
Total pre-tax gains/(losses) recognized in income		$(9)	$5	$1	$—

		For the Nine Months Ended September 30,
		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2021	2020	2021	2020
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$443	$23	$415	$20
Noncurrent	Deferred derivative gains	106	15	97	14
Total deferred gains/(losses)		$549	$38	$512	$34
Current	Deferred derivative losses	$25	$12	$22	$9
Current	Recoverable energy costs	(30)	(163)	(29)	(144)
Noncurrent	Deferred derivative losses	(16)	(73)	(13)	(70)
Total deferred gains/(losses)		$(21)	$(224)	$(20)	$(205)
Net deferred gains/(losses)		$528	$(186)	$492	$(171)
	Income Statement Location
Pre-tax gains/(losses) recognized in income
	Gas purchased for resale	$4	$(3)	$—	$—
	Non-utility revenue	(22)	3	—	—
	Other operations and maintenance expense	5	(5)	5	(5)
	Other interest expense	45	(82)	—	—
Total pre-tax gains/(losses) recognized in income		$32	$(87)	$5	$(5)

The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at September 30, 2021:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	23,870,400	39,914	280,838,997	4,704,000
CECONY	21,401,150	29,700	261,010,000	4,704,000

(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.

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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 September 30, 2021, Con Edison and CECONY had $689 million and $424 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 $95 million with independent system operators, $103 million with non-investment grade/non-rated counterparties, $160 million with commodity exchange brokers, and $331 million with investment-grade counterparties. CECONY’s net credit exposure consisted of $131 million with commodity exchange brokers and $293 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 September 30, 2021:

(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$211		$176
Collateral posted	170		165
Additional collateral (b) (downgrade one level from current ratings)	24		4
Additional collateral (b) (downgrade to below investment grade from current ratings)	83	(c)	54	(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 $14 million of additional collateral at September 30, 2021. 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 September 30, 2021, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $72 million.

Note O – 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

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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 September 30, 2021 and December 31, 2020 are summarized below.

	2021					2020
(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)	$215	$533	$29	$(380)	$397	$19	$42	$4	$53	$118
Interest rate swaps (a)(b)(c)	—	5	—	—	5	—	—	—	—	—
Other (a)(b)(d)	479	136	—	—	615	431	126	—	—	557
Total assets	$694	$674	$29	$(380)	$1,017	$450	$168	$4	$53	$675
Derivative liabilities:
Commodity (a)(b)(c)	$40	$462	$34	$(272)	$264	$7	$296	$23	$46	$372
Interest rate swaps (a)(b)(c)	—	65	—	—	65	—	106	—	—	106
Total liabilities	$40	$527	$34	$(272)	$329	$7	$402	$23	$46	$478
CECONY
Derivative assets:
Commodity (a)(b)(c)	$142	$367	$2	$(201)	$310	$15	$20	$—	$(16)	$19
Other (a)(b)(d)	460	128	—	—	588	411	120	—	—	531
Total assets	$602	$495	$2	$(201)	$898	$426	$140	$—	$(16)	$550
Derivative liabilities:
Commodity (a)(b)(c)	$—	$253	$19	$(61)	$211	$3	$274	$10	$(19)	$268

(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 nine months ended September 30, 2021. Con Edison and CECONY had $1 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2020 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2020 to less than three years as of December 31, 2020.

(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, and 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 September 30, 2021 and December 31, 2020, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.

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(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.

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 and interest rate swaps. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives and interest rate swaps. Fair value and changes in fair value of commodity derivatives and interest rate swaps 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 September 30, 2021	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
Con Edison – Commodity
Electricity	$11	Discounted Cash Flow	Forward energy prices (a)	$15.00-$130.75 per MWh
	(17)	Discounted Cash Flow	Forward capacity prices (a)	$0.26-$12.93 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(4.21)-$10.11 per MWh
Total Con Edison—Commodity	$(5)
CECONY – Commodity
Electricity	$(9)	Discounted Cash Flow	Forward energy prices (a)	$26.80-$98.51 per MWh
	(10)	Discounted Cash Flow	Forward capacity prices (a)	$0.70-$12.93 per kW-month
Transmission Congestion Contracts	2	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.63-$5.63 per MWh
Total CECONY—Commodity	$(17)

(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 September 30, 2021 and 2020 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance as of July 1,	$(9)	$(14)	$(7)	$(7)
Included in earnings	21	—	1	—
Included in regulatory assets and liabilities	(17)	(3)	(11)	(1)
Settlements	—	—	—	(1)
Ending balance as of September 30,	$(5)	$(17)	$(17)	$(9)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance as of January 1,	$(19)	$(16)	$(10)	$(6)
Included in earnings	20	(7)	(2)	(3)
Included in regulatory assets and liabilities	(9)	(3)	(7)	(3)
Settlements	3	9	2	3
Ending balance as of September 30,	$(5)	$(17)	$(17)	$(9)

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.

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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 on the consolidated income statement for the three months ended September 30, 2021 and 2020 ($20 million gain and $1 million gain, respectively). Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues on the consolidated income statement for the nine months ended September 30, 2021 and 2020 ($24 million gain and $2 million gain, respectively).

Note P – 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 2020, 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.

Clean Energy Businesses

In June 2021, a subsidiary of the Clean Energy Businesses sold substantially all of its membership interest in a renewable electric project, and retained an equity interest of $11 million in the project which, as of September 30, 2021, is valued at $7 million and is accounted for as an equity method investment. See Note R. The earnings of the project are determined using the hypothetical liquidation at book value (HLBV) method of accounting, and such earnings were not material for the three and nine months ended September 30, 2021. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the renewable electric project is not held by the Clean Energy Businesses.

In February 2021, a subsidiary of the Clean Energy Businesses entered into an agreement relating to certain projects (CED Nevada Virginia) with a noncontrolling tax equity investor to which a percentage of earnings, tax attributes and cash flows will be allocated. CED Nevada Virginia is a consolidated entity 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 CED Nevada Virginia during construction of the projects, and upon commercial operation, is held by the Clean Energy Businesses.

For the three months ended September 30, 2021, the hypothetical liquidation at book value (HLBV) method of accounting for CED Nevada Virginia resulted in a $74 million loss ($56 million, after-tax) for the tax equity investor and an equivalent amount of income for Con Edison.

For the nine months ended September 30, 2021, the HLBV method of accounting for CED Nevada Virginia resulted in a $127 million loss ($96 million, after tax) for the tax equity investor and an equivalent amount of income for Con Edison.

In December 2018, the Clean Energy Businesses 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

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Equity Projects is held by the Clean Energy Businesses. 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 September 30, 2021, the HLBV method of accounting for the Tax Equity Projects resulted in an immaterial amount of income for the tax equity investor and $14 million of income ($11 million, after-tax) for Con Edison. For the three months ended September 30, 2020, the HLBV method of accounting for the Tax Equity Projects resulted in $9 million of income ($7 million, after-tax) for the tax equity investor and $7 million of income ($5 million, after-tax) for Con Edison.

For the nine months ended September 30, 2021, the HLBV method of accounting for the Tax Equity Projects resulted in $8 million of income ($6 million, after tax) for the tax equity investor and $27 million of income ($20 million, after tax) for Con Edison. For the nine months ended September 30, 2020, the HLBV method of accounting for the Tax Equity Projects resulted in $38 million of income ($29 million, after tax) for the tax equity investor and a $3 million loss ($2 million, after tax) for Con Edison.

Con Edison has determined that the use of HLBV accounting is reasonable and appropriate to attribute income and loss to the tax equity investors. Using the HLBV method, the company's earnings from the projects are adjusted to reflect the income or loss allocable to the tax equity investors calculated based on how the project would allocate and distribute its cash if it were to sell all of its assets for their carrying amounts and liquidate at a particular point in time. Under the HLBV method, the company calculates the liquidation value allocable to the tax equity investors at the beginning and end of each period based on the contractual liquidation waterfall and adjusts its income for the period to reflect the change in the liquidation value allocable to the tax equity investors.

At September 30, 2021 and December 31, 2020, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs:

	Tax Equity Projects
	Great Valley Solar (c)(d)		Copper Mountain - Mesquite Solar  (c)(e)		CED Nevada Virginia (c)(h)
(Millions of Dollars)	2021	2020	2021	2020	2021
Non-utility property, less accumulated depreciation (f)(g)	$278	$284	$435	$446	$647
Other assets	40	39	174	176	57
Total assets (a)	$318	$323	$609	$622	$704
Other liabilities	14	13	79	71	328
Total liabilities (b)	$14	$13	$79	$71	$328

(a)The assets of the Tax Equity Projects and CED Nevada Virginia 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 CED Nevada Virginia 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 $88 million and $82 million at September 30, 2021 and December 31, 2020, 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 $122 million and $134 million at September 30, 2021 and December 31, 2020, respectively.

(f)Non-utility property is reduced by accumulated depreciation of $24 million for Great Valley Solar, $40 million for Copper Mountain - Mesquite Solar, and $5 million for CED Nevada Virginia at September 30, 2021.

(g)Non-utility property is reduced by accumulated depreciation of $18 million for Great Valley Solar and $30 million for Copper Mountain - Mesquite Solar at December 31, 2020.

(h)CED Nevada Virginia consists of the Copper Mountain Solar 5, Battle Mountain Solar and Water Strider Solar projects for which the noncontrolling interest of the tax equity investor was $128 million at September 30, 2021.

Note Q – New Financial Accounting Standards

In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (ASU 2020-04). In 2017, the United Kingdom’s Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit the London Interbank Offered Rate (LIBOR), a benchmark interest rate referenced in a variety of agreements, after 2021. In March 2021, the United Kingdom's Financial Conduct Authority confirmed that U.S. Dollar LIBOR will no longer be published after

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December 31, 2021 for one-week and two-month U.S. Dollar LIBOR tenors, and after June 30, 2023 for all other U.S. Dollar LIBOR tenors. ASU 2020-04 provides entities with optional expedients and exceptions for applying generally accepted accounting principles to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another reference rate expected to be discontinued. In January 2021, the FASB issued amendments to the guidance through ASU 2021-01 to include all contract modifications and hedging relationships affected by reference rate reform, including those that do not directly reference LIBOR or another reference rate expected to be discontinued, and clarify which optional expedients may be applied to them. The guidance can be applied prospectively. The optional relief is temporary and generally cannot be applied to contract modifications and hedging relationships entered into or evaluated after December 31, 2022. The Companies do not expect the new guidance to have a material impact on their financial position, results of operations or liquidity.

Note R – Dispositions

In April 2021, a subsidiary of the Clean Energy Businesses entered into an agreement to sell substantially all of its membership interests in a renewable electric project that it developed and also all of its membership interests in a renewable electric production project that it acquired in 2016. The sales were completed in June 2021. The combined carrying value of both projects was approximately $180 million in June 2021. The net pre-tax gain on the sales was $3 million ($2 million after-tax) and was included within "Other operations and maintenance" on Con Edison's consolidated income statement for the nine months ended September 30, 2021. The retained portion of the membership interest in the renewable electric project, of $11 million, was calculated based on a discounted cash flow of future projected earnings, and the retained portion is accounted for as an equity method investment. The portion of the gain attributable to the retained portion of the membership interest was not material for the nine months ended September 30, 2021. See Note P.

In July 2021, a subsidiary of CET Gas and its joint venture partner completed the first of two closings for the sale of their combined interests in Stagecoach. The first closing was completed for a total sale price of $1,195 million, of which $614 million, including working capital, was attributed to CET Gas. See "Investments" in Note A.

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

This combined management’s discussion and analysis of financial condition and results of operations (MD&A) relates to the consolidated financial statements (the Third Quarter Financial Statements) included in this report of two separate registrants: Consolidated Edison, Inc. (Con Edison) and Consolidated Edison Company of New York, Inc. (CECONY). As used in this report, the term the “Companies” refers to Con Edison and CECONY. CECONY is a subsidiary of Con Edison and, as such, information in this management’s discussion and analysis about CECONY applies to Con Edison.

This MD&A should be read in conjunction with the Third Quarter Financial Statements and the notes thereto and the MD&A in Item 7 of the Companies’ combined Annual Report on Form 10-K for the year ended December 31, 2020 (File Nos. 1-14514 and 1-1217, the Form 10-K) and the MD&A in Part 1, Item 2 of the Companies' combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2021 and June 30, 2021 (File Nos. 1-14514 and 1-1217).

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

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

		Con Edison
CECONY	O&R		Clean Energy Businesses	Con Edison Transmission
	•RECO			•CET Electric
				•CET Gas

Con Edison’s principal business operations are those of CECONY, O&R, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business operations are its regulated electric, gas and steam delivery businesses. O&R’s principal business operations are its regulated electric and gas delivery businesses. The Clean Energy Businesses develop, own and operate renewable and sustainable energy infrastructure projects and provide energy-related products and services to wholesale and retail customers. Con Edison Transmission invests in and seeks to develop electric transmission projects and manages, through joint ventures, both electric and gas assets. CET Gas and CECONY are considering strategic alternatives with respect to their interests in Honeoye Storage Corporation (Honeoye), of which CET owns a 71.2 percent interest and CECONY owns a 28.8 percent interest.

Con Edison seeks to provide shareholder value through continued dividend growth, supported by earnings growth in regulated utilities and contracted electric and gas assets. The company invests to provide reliable, resilient, safe and clean energy critical for its New York customers. The company is an industry leading owner and operator of contracted, large-scale solar generation in the United States. Con Edison is a responsible neighbor, helping the communities it serves become more sustainable.

CECONY

Electric

CECONY provides electric service to approximately 3.5 million customers in all of New York City (except a part of Queens) and most of Westchester County, an approximately 660 square mile service area with a population of more than nine million.

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Electric Supply

In 2019, the New York State Department of Environmental Conservation (NYSDEC) issued regulations that may require the retirement or seasonal unavailability of fossil-fueled electric generating units owned by CECONY and others in New York City. The NYSDEC rule limits nitrous oxides (NOx) emissions during the ozone season from May through September and affects older peaking units that are generally located downstate and needed during periods of high electric demand or for local reliability purposes. Compliance with the rule will require affected units (approximately 1,400 MW in CECONY's service territory, of which 65 MW is owned by CECONY) to cease operation during the ozone season, install emission controls, repower, or retire by 2023 or 2025. The NYISO, in its 2020 Reliability Needs Assessment study that was approved by the NYISO board, reported local and bulk transmission system reliability needs that are expected to be caused by the retirement or unavailability of some of the impacted units. In January 2021, CECONY updated its Local Transmission Plan (LTP) to address the identified reliability needs on its local system through the construction of three transmission projects, the Reliable Clean City (RCC) projects. In addition, CECONY continues to monitor forecasted system voltage performance and if a need for support persists in the forecast, CECONY will propose solutions in a subsequent LTP update. CECONY estimates that the costs of the RCC projects to solve the local reliability needs to be approximately $780 million over four years. In April 2021, the NYSPSC approved CECONY’s December 2020 petition to recover $780 million of costs to construct the RCC projects to solve the local reliability needs.

During the summer of 2021, electric peak demand in CECONY's service area was 12,039 MW (which occurred on June 30, 2021). At design conditions, electric peak demand in the company's service area would have been approximately 12,336 MW in 2021 compared to the company's forecast of 12,880 MW. The lower peak demand at design conditions as compared to the forecast was primarily due to the slower than expected recovery of electric demand in CECONY's territory during the emergence from the COVID-19 pandemic. The company decreased its five-year forecast of average annual change in electric peak demand in its service area at design conditions from approximately 0.8 percent (for 2021 to 2025) to approximately 0.4 percent (for 2022 to 2026).

Gas

CECONY delivers gas to approximately 1.1 million customers in Manhattan, the Bronx, parts of Queens and most of Westchester County.

In May 2021, CECONY decreased its five-year forecast of average annual growth of the firm peak gas demand in its service area at design conditions from approximately 1.4 percent (for 2021 to 2025) to approximately 1.3 percent (for 2022 to 2026). The slight decrease reflects the negative impact that the current economy and lingering effects of the COVID-19 pandemic is expected to have on large new construction, usage from existing large customers, as well as the projected number of applications for firm gas service in CECONY's service territory. The decrease also reflects an expected increase in customers’ energy efficiency measures and electrification of space heating.

Steam

CECONY operates the largest steam distribution system in the United States by producing and delivering approximately 16,981 MMlb of steam annually to approximately 1,558 customers in parts of Manhattan.

In June 2021, CECONY changed its five-year forecast of average annual growth in the peak steam demand in its service area at design conditions from a 0.4 percent decrease to a 0.1 percent increase (for 2022 to 2026), as steam sales are expected to recover from the decrease in customer usage during the COVID-19 pandemic.

O&R

Electric

O&R and its utility subsidiary, Rockland Electric Company (RECO) (together referred to herein as O&R) provide electric service to approximately 0.3 million customers in southeastern New York and northern New Jersey, an approximately 1,300 square mile service area.

During the summer of 2021, electric peak demand in O&R's service area was 1,520 MW (which occurred on June 30, 2021). At design conditions, electric peak demand in the company's service area would have been approximately 1,575 MW in 2021 compared to the company's forecast of 1,530 MW. The difference at design conditions is higher than expected due to a decrease in residential vacancies and faster recovery of electric demand in O&R's service territory during the emergence from the COVID-19 pandemic. The company increased its five-year

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forecast of average annual change in electric peak demand in its service area at design conditions from approximately (0.5) percent (for 2021 to 2025) to approximately (0.3) percent (for 2022 to 2026).

Gas

O&R delivers gas to over 0.1 million customers in southeastern New York.

In May 2021, O&R decreased its five-year forecast of average annual growth of the firm peak gas demand in its service area at design conditions from approximately 0.2 percent (for 2021 to 2025) to approximately 0.1 percent (for 2022 to 2026). The decrease reflects an expected increase in customers' energy efficiency measures and electrification of space heating.

Clean Energy Businesses

Con Edison Clean Energy Businesses, Inc., together with its subsidiaries, are referred to in this report as the Clean Energy Businesses. The Clean Energy Businesses develop, own and operate renewable and sustainable energy infrastructure projects and provide energy-related products and services to wholesale and retail customers.

Con Edison Transmission

Con Edison Transmission, Inc. invests in electric transmission projects and manages, through joint ventures, both electric and gas assets while seeking to develop electric transmission projects through its wholly-owned subsidiaries, Consolidated Edison Transmission, LLC (CET Electric) and Con Edison Gas Pipeline and Storage, LLC (CET Gas). CET Electric owns a 45.7 percent interest in New York Transco LLC, which owns and has been selected to build additional electric transmission assets in New York. In May 2021, a CET Gas subsidiary entered into a purchase and sale agreement pursuant to which it agreed to sell its 50 percent interest in Stagecoach Gas Services LLC (Stagecoach), a joint venture that owned and operated an existing gas pipeline and storage business located in northeastern Pennsylvania and the southern tier of New York, and in July 2021 the transaction was substantially completed. See "Investments" in Note A and Note R to the Third Quarter Financial Statements. Also, CET Gas and CECONY own 71.2 percent and 28.8 percent interests, respectively, in Honeoye, which operates a gas storage facility in upstate New York. CET Gas and CECONY are considering strategic alternatives with respect to their interests in Honeoye. At September 30, 2021, the consolidated carrying value of Honeoye was $25 million. In addition, CET Gas owns a 10.6 percent interest (that is expected to be reduced to 8.5 percent based on the current project cost estimate and CET Gas’ previous capping of its cash contributions to the joint venture) in Mountain Valley Pipeline LLC (MVP), a joint venture developing a proposed 300-mile gas transmission project in West Virginia and Virginia. Con Edison Transmission, Inc., together with CET Electric and CET Gas, are referred to in this report as Con Edison Transmission.

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

	For the Three Months Ended September 30, 2021						For the Nine Months Ended September 30, 2021						At September 30, 2021
(Millions of Dollars, except percentages)	Operating Revenues			Net Income for Common Stock			Operating Revenues			Net Income for Common Stock			Assets
CECONY	$3,092	86	%	$418	78	%	$8,784	85	%	$1,011	90	%	$52,178	83	%
O&R	257	7		26	5		699	7		53	5		3,344	5
Total Utilities	3,349	93		444	83		9,483	92		1,064	95		55,522	88
Clean Energy Businesses (a)	264	7		106	20		779	8		223	20		6,604	10
Con Edison Transmission (b)	1	—		1	—		3	—		(142)	(13)		493	1
Other (c)	(1)	—		(13)	(3)		(4)	—		(23)	(2)		319	1
Total Con Edison	$3,613	100	%	$538	100	%	$10,261	100	%	$1,122	100	%	$62,938	100	%

(a)Net income for common stock from the Clean Energy Businesses for the three and nine months ended September 30, 2021 includes $(9) million and $20 million, respectively, of net after-tax mark-to-market income/(loss) and reflects $52 million (after-tax) and $87 million (after-tax), respectively, of income attributable to the non-controlling interest of a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. Net income for common stock from the Clean Energy Businesses for the nine months ended September 30, 2021 includes $(3) million (after-tax) for the loss from the sale of a renewable electric production project. See Note P to the Third Quarter Financial Statements.

(b)Net income for common stock from Con Edison Transmission for the nine months ended September 30, 2021 includes $(153) million of a net after-tax impairment loss related to its investment in Stagecoach. See Note A to the Third Quarter Financial Statements.

(c)Other includes parent company and consolidation adjustments. Net income for common stock for the three and nine months ended September 30, 2021 includes $(4) million (after-tax) and $(7) million (after-tax), respectively, of loss attributable to the non-controlling interest of a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. Net income for common stock for the nine months ended September 30, 2021 includes $6 million of income tax impact for the impairment loss related to Con Edison's investment in Stagecoach and $(2) million of net after-tax mark-to-market loss.

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Coronavirus Disease 2019 (COVID-19) Impacts

The Companies continue to respond to the Coronavirus Disease 2019 (COVID-19) global pandemic by working to reduce the potential risks posed by its spread to employees, customers and other stakeholders. The Companies continue to employ an incident command structure led by a pandemic planning team. The Companies support employee health and facility hygiene through regular cleaning and disinfecting of all work and common areas, promoting social distancing, allowing employees to work remotely and directing employees to stay at home if they are experiencing COVID or flu-like symptoms. Employees who test positive for COVID-19 are directed to quarantine at home and are evaluated for close, prolonged contact with other employees that would require those employees to quarantine at home. Following the Centers for Disease Control and Prevention guidelines, sick or quarantined employees return to work when they can safely do so. The Utilities continue to provide critical electric, gas and steam service to customers during the pandemic. Additional safety protocols have been implemented to protect employees, customers and the public, when work at customer premises is required.

On October 22, 2021, in response to President Biden's Executive Order 14042, the Companies announced that they are committed to complying with the mandate for employees of federal contractors and subcontractors to be fully vaccinated against COVID-19 by the federally-required deadline (January 4, 2022), unless employees are legally entitled to an accommodation. The Companies are continuing to monitor the situation closely and are implementing appropriate measures to mitigate any workforce and cost impacts that may occur.

Below is additional information related to the effects of the COVID-19 pandemic and the Companies’ actions. Also, see “COVID-19 Regulatory Matters” in Note B to the Third Quarter Financial Statements.

Impact of CARES Act and 2021 Appropriations Act on Accounting for Income Taxes

In response to the economic impacts of the COVID-19 pandemic, the Coronavirus Aid, Relief, and Economic Security (CARES) Act became law on March 27, 2020. The CARES Act has several key business tax relief measures that may present potential cash benefits and/or refund opportunities for Con Edison and its subsidiaries, including permitting a five-year carryback of a net operating loss (NOL) for tax years 2018, 2019 and 2020, temporary removal of the 80 percent limitation of NOL carryforwards against taxable income for tax years before 2021, temporary relaxation of the limitations on interest deductions, Employee Retention Tax Credit and deferral of payments of employer payroll taxes.

Con Edison carried back its NOL of $29 million from tax year 2018 to tax year 2013. This allowed Con Edison, mostly at the Clean Energy Businesses, to receive a $2.5 million net tax refund and to recognize a discrete income tax benefit of $4 million in 2020, due to the higher federal statutory tax rate in 2013. See "Income Tax" in Note J. Con Edison and its subsidiaries did not have a federal NOL in tax years 2019 or 2020.

Con Edison and its subsidiaries benefited by the increase in the percentage for calculating the limitation on the interest expense deduction from 30 percent of Adjusted Taxable Income (ATI) to 50 percent of ATI in 2019 and 2020, which allowed the Companies to deduct 100 percent of their interest expense. For 2021, the limitation on interest expense for computing ATI has reverted back to 30 percent.

The Companies qualify for an employee retention tax credit created under the CARES Act for "eligible employers" related to governmental authorities imposing restrictions that partially suspended their operations for a portion of their workforce due to the COVID-19 pandemic and the Companies continued to pay them. For the year ended December 31, 2020, Con Edison and CECONY recognized a tax benefit to Taxes, other than income taxes of $10 million and $7 million, respectively.

The CARES Act also allows employers to defer payments of the employer share of Social Security payroll taxes that would have otherwise been owed from March 27, 2020 through December 31, 2020. The Companies deferred the payment of employer payroll taxes for the period April 1, 2020 through December 31, 2020 of approximately $71 million ($63 million of which is for CECONY). The Companies will repay half of this liability by December 31, 2021 and the other half by December 31, 2022.

In December 2020, the Consolidated Appropriations Act, 2021 (the 2021 Appropriations Act) was signed into law. The 2021 Appropriations Act, among other things, extends the expiring employee retention tax credit to include qualified wages paid in the first two quarters of 2021, increases the qualified wages paid to an employee from 50 percent up to $10,000 annually in 2020 to 70 percent up to $10,000 per quarter in 2021 and increases the maximum employee retention tax credit amount an employer can take per employee from $5,000 in 2020 to $14,000 in the first two quarters of 2021. In March 2021, the American Rescue Plan Act was signed into law that expanded the

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2021 Appropriations Act to extend the period for eligible employers to receive the employer retention credit from June 30, 2021 to December 31, 2021.

Supply Chain Matters

The Utilities have been impacted, and may continue to be impacted, by global and U.S. supply chain disruptions causing shortages of, and increased pricing pressure on, among other things, certain raw materials, labor, microprocessors and microchips. The Utilities have used mitigation strategies in an effort to minimize these supply chain issues, such as increasing inventory and storage of specified materials, identifying alternate distributors and maintaining regular communications with key suppliers. These supply chain disruptions have not had a material impact on the Utilities’ net income, cash flows and financial condition, but have resulted in increased prices and lead times for certain orders of materials and equipment needed by the Utilities in their operations.

Accounting Considerations

Due to the COVID-19 pandemic and subsequent New York State on PAUSE and related executive orders (that have since been lifted), decline in business, bankruptcies, layoffs and furloughs, among other factors, both commercial and residential customers have had and may continue to have increased difficulty paying their utility bills. In June 2020, the state of New York enacted a law prohibiting New York utilities, including CECONY and O&R, from disconnecting residential customers, and starting in May 2021 small business customers, during the COVID-19 state of emergency, which ended in June 2021. In addition, such prohibitions will apply for an additional 180 days after the state of emergency ends (December 21, 2021) for residential and small business customers who have experienced a change in financial circumstances due to the COVID-19 pandemic. CECONY and O&R have existing allowances for uncollectible accounts established against their customer accounts receivable balances that are reevaluated each quarter and updated accordingly. Changes to the Utilities’ reserve balances that result in write-offs of customer accounts receivable balances are not reflected in rates during the term of the current rate plans. During the third quarter of 2021, the potential economic impact of the COVID-19 pandemic was also considered in forward-looking projections related to write-off and recovery rates, resulting in increases to the customer allowance for uncollectible accounts as detailed herein. CECONY’s and O&R’s allowances for uncollectible customer accounts reserve increased from $138 million and $8.7 million at December 31, 2020 to $300 million and $12.6 million at September 30, 2021, respectively. See "COVID-19 Regulatory Matters" in Note B and Note L to the Third Quarter Financial Statements.

The Companies test goodwill for impairment at least annually or whenever there is a triggering event, and test long-lived and intangible assets for recoverability when events or changes in circumstances indicate that the carrying value of long-lived or intangible assets may not be recoverable. The Companies identified no triggering events or changes in circumstances related to the COVID-19 pandemic that would indicate that the carrying value of goodwill, long-lived or intangible assets may not be recoverable at September 30, 2021.

New York State Legislation

In April 2021, New York State passed a law that increases the corporate franchise tax rate on business income from 6.5% to 7.25%, retroactive to January 1, 2021, for taxpayers with taxable income greater than $5 million. The law also reinstates the business capital tax at 0.1875%, not to exceed a maximum tax liability of $5 million per taxpayer. New York State requires a corporate franchise taxpayer to calculate and pay the highest amount of tax under the three alternative methods: a tax on business income; a tax on business capital; or a fixed dollar minimum. The provisions to increase the corporate franchise tax rate and reinstate a capital tax are scheduled to expire after 2023 and are not expected to have a material impact on the Companies’ financial position, results of operations or liquidity. In addition, the new law created a program that allows eligible residential renters in New York State who require assistance with rent and utility bills to have up to twelve months of electric and gas utility bill arrears forgiven, provided that such arrears were accrued on or after March 13, 2020. The program will be administered by the State Office of Temporary Disability Assistance in coordination with the New York State Department of Public Service and the NYSPSC. Under the program, CECONY and O&R would qualify for a refundable tax credit for New York State gross-receipts tax equal to the amount of arrears waived by the Utilities in the year that the arrears are waived and certified by the NYSPSC. See "COVID-19 Regulatory Matters” in Note B to the Third Quarter Financial Statements.

Liquidity and Financing

The Companies continue to monitor the impacts of the COVID-19 pandemic on the financial markets closely, including borrowing rates and daily cash collections. The Companies have been able to access the capital markets as needed since the start of the COVID-19 pandemic in March 2020. See Notes C and D to the Third Quarter Financial Statements. However, a continued economic downturn as a result of the COVID-19 pandemic has increased the amount of capital needed by the Utilities and could impact the costs of such capital.

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The decline in business activity in the Utilities’ service territory as a result of the COVID-19 pandemic and subsequent New York State on PAUSE and related executive orders (that have since been lifted), resulted in a slower recovery in cash of outstanding customer accounts receivable balances in 2020 and for the nine months ended September 30, 2021. These trends will likely continue through the remainder of 2021.

The Utilities’ rate plans have revenue decoupling mechanisms in their New York electric and gas businesses that largely reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC per month and accumulate the deferred balances semi-annually under CECONY's electric rate plan (January through June and July through December, respectively) and annually under CECONY's gas rate plan and O&R New York's electric and gas rate plans (January through December). Differences are accrued with interest each month for CECONY's and O&R New York’s electric customers and after the annual deferral period ends for CECONY's and O&R New York’s gas customers for refund to, or recovery from customers, as applicable. Generally, the refund to or recovery from customers begins August and February of each year over an ensuing six-month period for CECONY's electric customers and February of each year over an ensuing twelve-month period for CECONY's gas and O&R New York's electric and gas customers. Although these revenue decoupling mechanisms are in place, lower billed sales revenues and higher uncollectible accounts have reduced and are expected to continue to reduce liquidity at the Utilities. Also, in March 2020, the Utilities began suspending service disconnections, certain collection notices, final bill collection agency activity, new late payment charges and certain other fees for all customers and such suspensions may continue through 2021.

For the nine months ended September 30, 2021, the estimated late payment charges and fees that were not billed by CECONY and O&R were approximately $46 million and $3 million lower than the amounts that were approved to be collected pursuant to their rate plans, respectively. These unbilled amounts have reduced and may continue to reduce liquidity at the Utilities. See "COVID-19 Regulatory Matters" in Note B and Note K to the Third Quarter Financial Statements.

Con Edison and the Utilities have a $2,250 million credit agreement (Credit Agreement) in place under which banks are committed to provide loans on a revolving credit basis until December 2023 ($2,200 million of commitments from December 2022). Con Edison and the Utilities have not entered into any loans under the Credit Agreement. See Note D to the Third Quarter Financial Statements.

Results of Operations

Net income for common stock and earnings per share for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2021	2020	2021	2020	2021	2020	2021	2020
(Millions of Dollars, except per share amounts)	Net Income for Common Stock		Earnings per Share		Net Income for Common Stock		Earnings per Share
CECONY	$418	$405	$1.19	$1.21	$1,011	$963	$2.92	$2.88
O&R	26	27	0.07	0.08	53	57	0.15	0.17
Clean Energy Businesses (a)	106	56	0.30	0.17	223	8	0.64	0.03
Con Edison Transmission (b)	1	15	—	0.04	(142)	42	(0.40)	0.13
Other (c)	(13)	(10)	(0.04)	(0.03)	(23)	(12)	(0.08)	(0.04)
Con Edison (d)	$538	$493	$1.52	$1.47	$1,122	$1,058	$3.23	$3.17

(a)Net income for common stock from the Clean Energy Businesses for the three and nine months ended September 30, 2021 includes $(9) million or $(0.03) a share and $20 million or $0.06 a share, respectively, of net after-tax mark-to-market income/(loss) and reflects $52 million or $0.15 a share (after-tax) and $87 million or $0.25 a share (after-tax), respectively, of income attributable to the non-controlling interest of a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. Net income for common stock from the Clean Energy Businesses for the nine months ended September 30, 2021 includes $(3) million or $(0.01) a share (after-tax) for the loss from the sale of a renewable electric production project. Net income for common stock from the Clean Energy Businesses for the three and nine months ended September 30, 2020 includes $5 million or $0.01 a share and $(60) million or $(0.18) a share, respectively, of net after-tax mark-to-market income/(loss) and reflects $7 million or $0.02 a share (after-tax) and $29 million or $0.08 a share (after-tax), respectively, of income attributable to the non-controlling interest of a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. See Note P to the Third Quarter Financial Statements.

(b)Net income for common stock from Con Edison Transmission for the nine months ended September 30, 2021 includes $(153) million or $(0.44) a share of net after-tax impairment loss related to its investment in Stagecoach. See Note A to the Third Quarter Financial Statements.

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(c)Other includes parent company and consolidation adjustments. Net income for common stock for the three and nine months ended September 30, 2021 includes $(4) million (after-tax) or $(0.01) a share (after-tax) and $(7) million (after-tax) or $(0.02) a share (after-tax), respectively, of loss attributable to the non-controlling interest of a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. Net income for common stock for the nine months ended September 30, 2021 includes $6 million or $0.01 a share of income tax impact for the impairment loss related to Con Edison Transmission’s investment in Stagecoach and $(2) million or $(0.01) a share of net after-tax mark-to-market loss. See Note A to the Third Quarter Financial Statements. Net income for common stock for the three and nine months ended September 30, 2020 includes $1 million (after-tax) and $2 million or $0.01 a share (after-tax), respectively, of income attributable to the non-controlling interest of a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. Net income for common stock from the Clean Energy Businesses for the nine months ended September 30, 2020 includes $5 million or $0.01 a share of net after-tax mark-to-market income.

(d)Earnings per share on a diluted basis were $1.52 a share and $1.47 a share for the three months ended September 30, 2021 and 2020, respectively, and $3.23 a share and $3.16 a share for the nine months ended September 30, 2021 and 2020, respectively.

The following tables present the estimated effect of major factors on earnings per share and net income for common stock for the three and nine months ended September 30, 2021 as compared with the 2020 period.

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Variation for the Three Months Ended September 30, 2021 vs. 2020
	Net Income for Common Stock (Millions of Dollars)	Earnings per Share
CECONY (a)
Higher electric rate base	$21	$0.06
Lower healthcare costs	5	0.02
Lower stock based compensation costs	5	0.01
Uncollected late payment charges and certain other fees associated with COVID-19	4	0.01
Higher uncollectibles written off and increase to reserve for uncollectibles, net of deferrals (that began in the third quarter of 2020) for uncollectibles associated with the Coronavirus Disease (COVID-19) pandemic	(18)	(0.05)
Higher storm-related costs	(3)	(0.01)
Dilutive effect of stock issuances	—	(0.07)
Other	(1)	0.01
Total CECONY	13	(0.02)
O&R (a)
Higher storm-related costs	(4)	(0.01)
Other	3	—
Total O&R	(1)	(0.01)
Clean Energy Businesses
HLBV effects	59	0.17
Net mark-to-market effects	(14)	(0.04)
Dilutive effect of stock issuances	—	(0.02)
Other	5	0.02
Total Clean Energy Businesses	50	0.13
Con Edison Transmission
Foregoing Allowance for Funds Used During Construction income starting in January 2021 until significant construction resumes on the Mountain Valley Pipeline	(11)	(0.03)
Other	(3)	(0.01)
Total Con Edison Transmission	(14)	(0.04)
Other, including parent company expenses
HLBV effects	(4)	(0.01)
Other	1	—
Total Other, including parent company expenses	(3)	(0.01)
Total Reported (GAAP basis)	$45	$0.05
a.    Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans and the weather-normalization clause applicable to their gas businesses, revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. In general, the Utilities recover on a current basis the fuel, gas purchased for resale and purchased power costs they incur in supplying energy to their full-service customers. Accordingly, such costs do not generally affect Con Edison’s results of operations.

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Variation for the Nine Months Ended September 30, 2021 vs. 2020
	Net Income for Common Stock (Millions of Dollars)	Earnings per Share
CECONY (a)
Higher electric rate base	$34	$0.10
Higher gas rate base	24	0.07
Weather impact on steam revenues	15	0.05
Lower incremental costs associated with the COVID-19 pandemic	8	0.02
Lower stock based compensation costs	3	0.01
Estimated food and medicine spoilage claims related to outages caused by Tropical Storm Isaias in 2020	4	0.01
Higher costs related to heat and storm-related events	(29)	(0.09)
Uncollected late payment charges and certain other fees associated with the COVID-19 pandemic	(7)	(0.02)
Higher uncollectibles written off and increase to reserve for uncollectibles, net of deferrals (that began in the third quarter of 2020) for uncollectibles associated with the COVID-19 pandemic	(2)	(0.01)
Dilutive effect of stock issuances	—	(0.11)
Other	(2)	0.01
Total CECONY	48	0.04
O&R (a)
Higher storm-related costs	(8)	(0.02)
Other	4	—
Total O&R	(4)	(0.02)
Clean Energy Businesses
Higher revenues	155	0.47
HLBV effects	116	0.33
Net mark-to-market effects	80	0.24
Gain on sale of a renewable electric project	4	0.01
Higher operations and maintenance expenses	(134)	(0.40)
Loss from sale of a renewable electric production project	(3)	(0.01)
Dilutive effect of stock issuances	—	(0.02)
Other	(3)	(0.01)
Total Clean Energy Businesses	215	0.61
Con Edison Transmission
Impairment losses on Stagecoach	(153)	(0.44)
Foregoing Allowance for Funds Used During Construction income starting in January 2021 until significant construction resumes on the Mountain Valley Pipeline	(33)	(0.10)
Other	2	—
Total Con Edison Transmission	(184)	(0.54)
Other, including parent company expenses
HLBV effects	(7)	(0.02)
Net mark-to-market effects	(2)	(0.01)
Impairment tax benefits on Stagecoach	6	0.01
Other	(8)	(0.01)
Total Other, including parent company expenses	(11)	(0.03)
Total Reported (GAAP basis)	$64	$0.06
a.    Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans and the weather-normalization clause applicable to their gas businesses, revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. In general, the Utilities recover on a current basis the fuel, gas purchased for resale and purchased power costs they incur in supplying energy to their full-service customers. Accordingly, such costs do not generally affect Con Edison’s results of operations.

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The Companies’ other operations and maintenance expenses for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars)	2021	2020	2021	2020
CECONY
Operations	$445	$423	$1,283	$1,210
Pensions and other postretirement benefits	(6)	(20)	(23)	(83)
Health care and other benefits	42	49	134	115
Regulatory fees and assessments (a)	99	94	252	253
Other	70	51	202	219
Total CECONY	650	597	1,848	1,714
O&R	83	79	240	232
Clean Energy Businesses	114	59	348	165
Con Edison Transmission	3	2	9	8
Other (b)	(1)	(1)	(2)	(3)
Total other operations and maintenance expenses	$849	$736	$2,443	$2,116

(a)Includes Demand Side Management, System Benefit Charges and Public Service Law 18A assessments which are collected in revenues.

(b)Includes parent company and consolidation adjustments.

A discussion of the results of operations by principal business segment for the three and nine months ended September 30, 2021 and 2020 follows. For additional business segment financial information, see Note M to the Third Quarter Financial Statements.

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The Companies’ results of operations for the three months ended September 30, 2021 and 2020 were as follows:

	CECONY		O&R		Clean Energy Businesses		Con Edison Transmission		Other (a)		Con Edison (b)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020	2021	2020	2021	2020
Operating revenues	$3,092	$2,872	$257	$238	$264	$222	$1	$1	$(1)	$—	$3,613	$3,333
Purchased power	481	447	68	56	—	—	—	—	(1)	—	548	503
Fuel	44	24	—	—	—	—	—	—	—	—	44	24
Gas purchased for resale	61	38	13	9	9	8	—	—	—	—	83	55
Other operations and maintenance	650	597	83	79	114	59	3	2	(1)	(1)	849	736
Depreciation and amortization	429	401	24	23	58	58	—	—	1	—	512	482
Taxes, other than income taxes	699	643	22	22	4	5	—	1	2	2	727	673
Operating income	728	722	47	49	79	92	(2)	(2)	(2)	(1)	850	860
Other income (deductions)	(23)	(38)	(4)	(4)	—	3	5	27	—	(1)	(22)	(13)
Net interest expense	197	182	10	10	18	22	1	4	6	8	232	226
Income before income tax expense	508	502	33	35	61	73	2	21	(8)	(10)	596	621
Income tax expense	90	97	7	8	24	8	1	6	5	—	127	119
Net income	$418	$405	$26	$27	$37	$65	$1	$15	$(13)	$(10)	$469	$502
Income (loss) attributable to non-controlling interest	—	—	—	—	(69)	9	—	—	—	—	(69)	9
Net income for common stock	$418	$405	$26	$27	$106	$56	$1	$15	$(13)	$(10)	$538	$493

(a)Includes parent company and consolidation adjustments.

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

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CECONY

	For the Three Months Ended September 30, 2021				For the Three Months Ended September 30, 2020
(Millions of Dollars)	Electric	Gas	Steam	2021 Total	Electric	Gas	Steam	2020 Total	2021-2020 Variation
Operating revenues	$2,730	$307	$55	$3,092	$2,562	$259	$51	$2,872	$220
Purchased power	473	—	8	481	443	—	4	447	34
Fuel	39	—	5	44	18	—	6	24	20
Gas purchased for resale	—	61	—	61	—	38	—	38	23
Other operations and maintenance	516	92	42	650	469	87	41	597	53
Depreciation and amortization	324	82	23	429	305	74	22	401	28
Taxes, other than income taxes	544	120	35	699	514	94	35	643	56
Operating income	$834	$(48)	$(58)	$728	$813	$(34)	$(57)	$722	$6

Electric

CECONY’s results of electric operations for the three months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$2,730	$2,562	$168
Purchased power	473	443	30
Fuel	39	18	21
Other operations and maintenance	516	469	47
Depreciation and amortization	324	305	19
Taxes, other than income taxes	544	514	30
Electric operating income	$834	$813	$21

CECONY’s electric sales and deliveries for the three months ended September 30, 2021 compared with the 2020 period were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Three Months Ended						For the Three Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
Residential/Religious (b)	3,905	4,001	(96)	(2.4	%)		$1,025	$995	$30	3.0	%
Commercial/Industrial	2,645	2,627	18	0.7			652	556	96	17.3
Retail choice customers	6,274	6,294	(20)	(0.3)			861	784	77	9.8
NYPA, Municipal Agency and other sales	2,466	2,532	(66)	(2.6)			228	217	11	5.1
Other operating revenues (c)	—	—	—	—			(36)	10	(46)	Large
Total	15,290	15,454	(164)	(1.1)	%	(d)	$2,730	$2,562	$168	6.6	%

(a)Revenues from electric sales are subject to a revenue decoupling mechanism, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved.

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

(c)Other electric operating revenues generally reflect changes in the revenue decoupling mechanism current asset or regulatory liability and changes in regulatory assets and liabilities in accordance with other provisions of the company’s rate plans.

(d)After adjusting for variations, primarily weather and billing days, electric delivery volumes in CECONY’s service area increased 2.3 percent in the three months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $168 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to an increase in revenues from the electric rate plan ($95 million), higher purchased power expenses ($30 million) and higher fuel expenses ($21 million).

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Purchased power expenses increased $30 million in the three months ended September 30, 2021 compared with the 2020 period due to higher unit costs ($16 million) and purchased volumes ($15 million).

Fuel expenses increased $21 million in the three months ended September 30, 2021 compared with the 2020 period due to higher unit costs ($16 million) and purchased volumes from the company's electric generating facilities ($5 million).

Other operations and maintenance expenses increased $47 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to the timing of the recognition of uncollectible expense compared to the rate plan level ($21 million), higher costs for pensions and other postretirement benefits ($11 million), higher storm-related costs ($5 million) and higher surcharges for assessments and fees that are collected in revenues from customers ($5 million).

Depreciation and amortization increased $19 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher electric utility plant balances.

Taxes, other than income taxes increased $30 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher property taxes ($18 million), higher state and local taxes ($6 million) and lower deferral of under-collected property taxes ($6 million).

Gas

CECONY’s results of gas operations for the three months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$307	$259	$48
Gas purchased for resale	61	38	23
Other operations and maintenance	92	87	5
Depreciation and amortization	82	74	8
Taxes, other than income taxes	120	94	26
Gas operating income	$(48)	$(34)	$(14)

CECONY’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, 2021 compared with the 2020 period were:

	Thousands of Dt Delivered						Revenues in Millions (a)
	For the Three Months Ended						For the Three Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
Residential	4,158	4,314	(156)	(3.6	%)		$128	$117	$11	9.4	%
General	4,133	3,504	629	18.0			59	35	24	68.6
Firm transportation	8,943	8,668	275	3.2			80	70	10	14.3
Total firm sales and transportation	17,234	16,486	748	4.5		(b)	267	222	45	20.3
Interruptible sales (c)	1,198	1,882	(684)	(36.3)			6	4	2	50.0
NYPA	15,187	13,701	1,486	10.8			1	1	—	—
Generation plants	14,955	19,658	(4,703)	(23.9)			7	7	—	—
Other	4,193	4,457	(264)	(5.9)			6	6	—	—
Other operating revenues (d)	—	—	—	—			20	19	1	5.3
Total	52,767	56,184	(3,417)	(6.1	%)		$307	$259	$48	18.5	%

(a)Revenues from gas sales are subject to a weather normalization clause and a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

(b)After adjusting for variations, primarily billing days, firm gas sales and transportation volumes in the company’s service area decreased 3.1 percent in the three months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

(c)Includes 572 thousand and 676 thousand of Dt for the 2021 and 2020 periods, respectively, which are also reflected in firm transportation and other.

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(d)Other gas operating revenues generally reflect changes in the revenue decoupling mechanism and weather normalization clause current asset or regulatory liability and changes in regulatory assets and liabilities in accordance with other provisions of the company’s rate plans.

Operating revenues increased $48 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to an increase in revenues from the gas rate plan ($24 million) and higher gas purchased for resale ($23 million).

Gas purchased for resale increased $23 million in the three months ended September 30, 2021 compared with the 2020 period due to higher unit costs ($29 million), offset in part by lower purchased volumes ($7 million).

Other operations and maintenance expenses increased $5 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher costs for pensions and other postretirement benefits ($2 million), higher uncollectible expense ($2 million) and higher surcharges for assessments and fees that are collected in revenues from customers ($1 million).

Depreciation and amortization increased $8 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher gas utility plant balances.

Taxes, other than income taxes increased $26 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to lower deferral of under-collected property taxes ($16 million), higher property taxes ($8 million), and higher state and local taxes ($2 million).

Steam

CECONY’s results of steam operations for the three months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$55	$51	$4
Purchased power	8	4	4
Fuel	5	6	(1)
Other operations and maintenance	42	41	1
Depreciation and amortization	23	22	1
Taxes, other than income taxes	35	35	—
Steam operating income	$(58)	$(57)	$(1)

CECONY’s steam sales and deliveries for the three months ended September 30, 2021 compared with the 2020 period were:

	Millions of Pounds Delivered						Revenues in Millions
	For the Three Months Ended						For the Three Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
General	4	7	(3)	(42.9	%)		$2	$1	$1	Large
Apartment house	588	617	(29)	(4.7)			13	12	1	8.3
Annual power	1,904	2,023	(119)	(5.9)			34	33	1	3.0
Other operating revenues (a)	—	—	—	—			6	5	1	20.0
Total	2,496	2,647	(151)	(5.7)	%	(b)	$55	$51	$4	7.8	%

(a)Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan.

(b)After adjusting for variations, primarily weather and billing days, steam sales and deliveries decreased 4.3 percent in the three months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $4 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher purchased power expenses ($4 million).

Purchased power increased $4 million in the three months ended September 30, 2021 compared with the 2020 period due to higher purchased volumes ($3 million) and unit costs ($1 million).

68

Fuel decreased $1 million in the three months ended September 30, 2021 compared with the 2020 period due to lower unit costs.

Other operations and maintenance expenses increased $1 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher costs for pension and other postretirement benefits.

Depreciation and amortization increased $1 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher steam utility plant balances.

Other Income (Deductions)

Other deductions decreased $15 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to lower costs associated with components of pension and other postretirement benefits other than service cost.

Net Interest Expense

Net Interest Expense increased $15 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher interest on long-term debt ($15 million).

Income Tax Expense

Income taxes decreased $7 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to an increase in the amortization of excess deferred federal income taxes due to the TCJA ($4 million) and a higher favorable tax adjustment for the 2020 tax return primarily due to an increase in the general business tax credit ($5 million), offset in part by higher income before income tax expense ($1 million) and lower flow-through tax benefits in 2021 for plant-related items ($1 million).

O&R

	For the Three Months Ended September 30, 2021			For the Three Months Ended September 30, 2020
(Millions of Dollars)	Electric	Gas	2021 Total	Electric	Gas	2020 Total	2021-2020 Variation
Operating revenues	$223	$34	$257	$208	$30	$238	$19
Purchased power	68	—	68	56	—	56	12
Gas purchased for resale	—	13	13	—	9	9	4
Other operations and maintenance	67	16	83	62	17	79	4
Depreciation and amortization	18	6	24	17	6	23	1
Taxes, other than income taxes	15	7	22	15	7	22	—
Operating income	$55	$(8)	$47	$58	$(9)	$49	$(2)

Electric

O&R’s results of electric operations for the three months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$223	$208	$15
Purchased power	68	56	12
Other operations and maintenance	67	62	5
Depreciation and amortization	18	17	1
Taxes, other than income taxes	15	15	—
Electric operating income	$55	$58	$(3)

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O&R’s electric sales and deliveries for the three months ended September 30, 2021 compared with the 2020 period were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Three Months Ended						For the Three Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
Residential/Religious (b)	581	647	(66)	(10.2	%)		$114	$110	$4	3.6	%
Commercial/Industrial	221	230	(9)	(3.9)			32	35	(3)	(8.6)
Retail choice customers	820	741	79	10.7			75	62	13	21.0
Public authorities	32	32	—	—			4	3	1	33.3
Other operating revenues (c)	—	—	—	—			(2)	(2)	—	—
Total	1,654	1,650	4	0.2	%	(d)	$223	$208	$15	7.2	%

(a)O&R’s New York electric delivery revenues are subject to a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. O&R’s electric sales in New Jersey are not subject to a decoupling mechanism, and as a result, changes in such volumes do impact revenues.

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

(c)Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s electric rate plan.

(d)After adjusting for weather and other variations, electric delivery volumes in O&R’s service area increased 2.9 percent in the three months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $15 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher purchased power expenses ($12 million) and higher revenues from the New York electric rate plan ($1 million).

Purchased power expenses increased $12 million in the three months ended September 30, 2021 compared with the 2020 period due to higher unit costs ($23 million), offset in part by lower purchased volumes ($10 million).

Other operations and maintenance expenses increased $5 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher storm-related costs.

Depreciation and amortization increased $1 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher electric utility plant balances.

Gas

O&R’s results of gas operations for the three months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$34	$30	$4
Gas purchased for resale	13	9	4
Other operations and maintenance	16	17	(1)
Depreciation and amortization	6	6	—
Taxes, other than income taxes	7	7	—
Gas operating income	$(8)	$(9)	$1

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O&R’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, 2021 compared with the 2020 period were:

	Thousands of Dt Delivered						Revenues in Millions (a)
	For the Three Months Ended						For the Three Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
Residential	900	724	176	24.3	%		$18	$13	$5	38.5	%
General	258	218	40	18.3			4	2	2	Large
Firm transportation	736	804	(68)	(8.5)			6	7	(1)	(14.3)
Total firm sales and transportation	1,894	1,746	148	8.5		(b)	28	22	6	27.3
Interruptible sales	844	787	57	7.2			—	1	(1)	Large
Generation plants	13	21	(8)	(38.1)			—	—	—	—
Other	26	30	(4)	(13.3)			1	—	1	—
Other gas revenues	—	—	—	—			5	7	(2)	(28.6)
Total	2,777	2,584	193	7.5	%		$34	$30	$4	13.3	%

(a)Revenues from New York gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

(b)After adjusting for weather and other variations, total firm sales and transportation volumes increased 2.7 percent in the three months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $4 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher gas purchased for resale ($4 million).

Gas purchased for resale increased $4 million in the three months ended September 30, 2021 compared with the 2020 period due to higher unit costs ($2 million) and higher purchased volumes ($1 million).

Other operations and maintenance expenses decreased $1 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to lower uncollectible accounts and lower pension costs.

Income Tax Expense

Income taxes decreased $1 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to lower income before income tax expense.

Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the three months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Three Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$264	$222	$42
Gas purchased for resale	9	8	1
Other operations and maintenance	114	59	55
Depreciation and amortization	58	58	—
Taxes, other than income taxes	4	5	(1)
Operating income	$79	$92	$(13)

Operating revenues increased $42 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher revenue from renewable electric production projects ($48 million), higher wholesale revenues ($9 million) and higher energy services revenues ($8 million), offset in part by net mark-to-market values ($23 million).

Gas purchased for resale increased $1 million in the three months ended September 30, 2021 compared with the 2020 period due to higher purchased volumes.

Other operations and maintenance expenses increased $55 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to higher costs from engineering, procurement and construction of renewable electric projects for customers.

71

Net Interest Expense

Net interest expense decreased $4 million in the three months ended September 30, 2021 compared with the 2020 period due to higher unrealized gains on interest rate swaps in the 2021 period.

Income Tax Expense

Income taxes increased $16 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to lower income attributable to non-controlling interest ($19 million), offset in part by lower income before income tax expense ($3 million).

Income (Loss) Attributable to Non-Controlling Interest

Income attributable to non-controlling interest decreased $78 million to a loss of $69 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to lower income attributable in the 2021 period to a tax equity investor in renewable electric projects accounted for under the HLBV method of accounting. See Note P to the Third Quarter Financial Statements.

Con Edison Transmission

Other Income (Deductions)

Other income decreased $22 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to the substantial completion of the sale of Stagecoach and CET Gas foregoing AFUDC income from MVP starting January 2021 until significant construction resumes. See "Investments" in Note A and R to the Third Quarter Financial Statements.

Income Tax Expense

Income taxes decreased $5 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to lower income before income tax expense ($4 million) and lower state income taxes ($1 million).

Other

Income Tax Expense

Income taxes increased $5 million in the three months ended September 30, 2021 compared with the 2020 period primarily due to lower consolidated state income tax benefits.

72

The Companies’ results of operations for the nine months ended September 30, 2021 and 2020 were as follows:

	CECONY		O&R		Clean Energy Businesses		Con Edison Transmission		Other (a)		Con Edison (b)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020	2021	2020	2021	2020
Operating revenues	$8,784	$8,072	$699	$647	$779	$566	$3	$3	$(4)	$(2)	$10,261	$9,286
Purchased power	1,294	1,065	157	127	—	—	—	—	(3)	—	1,448	1,192
Fuel	166	124	—	—	—	—	—	—	—	—	166	124
Gas purchased for resale	357	298	56	43	49	24	—	—	(1)	(1)	461	364
Other operations and maintenance	1,848	1,714	240	232	348	165	9	8	(2)	(3)	2,443	2,116
Depreciation and amortization	1,267	1,187	71	67	172	173	1	1	—	—	1,511	1,428
Taxes, other than income taxes	2,016	1,830	67	64	14	16	—	—	6	5	2,103	1,915
Operating income	1,836	1,854	108	114	196	188	(7)	(6)	(4)	(3)	2,129	2,147
Other income (deductions) (c)	(70)	(138)	(9)	(11)	—	4	(178)	78	(2)	(5)	(259)	(72)
Net interest expense	567	554	32	30	44	183	8	14	18	16	669	797
Income before income tax expense	1,199	1,162	67	73	152	9	(193)	58	(24)	(24)	1,201	1,278
Income tax expense	188	199	14	16	44	(36)	(51)	16	(1)	(12)	194	183
Net income	$1,011	$963	$53	$57	$108	$45	$(142)	$42	$(23)	$(12)	$1,007	$1,095
Income (loss) attributable to non-controlling interest	—	—	—	—	(115)	37	—	—	—	—	(115)	37
Net income for common stock	$1,011	$963	$53	$57	$223	$8	$(142)	$42	$(23)	$(12)	$1,122	$1,058

(a)Includes parent company and consolidation adjustments.

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

(c)For the nine months ended September 30, 2021, Con Edison Transmission recorded pre-tax impairment losses of $211 million ($147 million, after-tax) on its investment in Stagecoach. See “Investments” in Note A to the Third Quarter Financial Statements.

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CECONY

	For the Nine Months Ended September 30, 2021				For the Nine Months Ended September 30, 2020
(Millions of Dollars)	Electric	Gas	Steam	2021 Total	Electric	Gas	Steam	2020 Total	2021-2020 Variation
Operating revenues	$6,661	$1,730	$393	$8,784	$6,178	$1,509	$385	$8,072	$712
Purchased power	1,267	—	27	1,294	1,046	—	19	1,065	229
Fuel	107	—	59	166	56	—	68	124	42
Gas purchased for resale	—	357	—	357	—	298	—	298	59
Other operations and maintenance	1,450	277	121	1,848	1,322	269	123	1,714	134
Depreciation and amortization	959	239	69	1,267	904	216	67	1,187	80
Taxes, other than income taxes	1,541	367	108	2,016	1,437	286	107	1,830	186
Operating income	$1,337	$490	$9	$1,836	$1,413	$440	$1	$1,854	$(18)

Electric

CECONY’s results of electric operations for the nine months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$6,661	$6,178	$483
Purchased power	1,267	1,046	221
Fuel	107	56	51
Other operations and maintenance	1,450	1,322	128
Depreciation and amortization	959	904	55
Taxes, other than income taxes	1,541	1,437	104
Electric operating income	$1,337	$1,413	$(76)

CECONY’s electric sales and deliveries for the nine months ended September 30, 2021 compared with the 2020 period were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Nine Months Ended						For the Nine Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
Residential/Religious (b)	8,828	8,638	190	2.2	%		$2,415	$2,220	$195	8.8	%
Commercial/Industrial	6,981	7,145	(164)	(2.3)			1,657	1,407	250	17.8
Retail choice customers	16,310	17,014	(704)	(4.1)			2,008	1,838	170	9.2
NYPA, Municipal Agency and other sales	6,854	6,972	(118)	(1.7)			536	506	30	5.9
Other operating revenues (c)	—	—	—	—			45	207	(162)	(78.3)
Total	38,973	39,769	(796)	(2.0)	%	(d)	$6,661	$6,178	$483	7.8	%

(a)Revenues from electric sales are subject to a revenue decoupling mechanism, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved.

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

(c)Other electric operating revenues generally reflect changes in the revenue decoupling mechanism current asset or regulatory liability and changes in regulatory assets and liabilities in accordance with other provisions of the company’s rate plans.

(d)After adjusting for variations, primarily weather and billing days, electric delivery volumes in CECONY’s service area decreased 1.3 percent in the nine months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $483 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to an increase in revenues from the electric rate plan ($177 million), higher purchased power expenses ($221 million) and higher fuel expenses ($51 million).

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Purchased power expenses increased $221 million in the nine months ended September 30, 2021 compared with the 2020 period due to higher purchased volumes ($157 million) and higher unit costs ($64 million).

Fuel expenses increased $51 million in the nine months ended September 30, 2021 compared with the 2020 period due to higher unit costs.

Other operations and maintenance expenses increased $128 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher costs for pension and other postretirement benefits ($46 million), higher costs related to heat and storm-related events ($40 million), higher uncollectible expense ($6 million) and higher healthcare costs ($10 million).

Depreciation and amortization increased $55 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher electric utility plant balances.

Taxes, other than income taxes increased $104 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher property taxes ($70 million), higher state and local taxes ($17 million) and lower deferral of under-collected property taxes ($14 million).

Gas

CECONY’s results of gas operations for the nine months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$1,730	$1,509	$221
Gas purchased for resale	357	298	59
Other operations and maintenance	277	269	8
Depreciation and amortization	239	216	23
Taxes, other than income taxes	367	286	81
Gas operating income	$490	$440	$50

CECONY’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2021 compared with the 2020 period were:

	Thousands of Dt Delivered						Revenues in Millions (a)
	For the Nine Months Ended						For the Nine Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
Residential	39,231	37,161	2,070	5.6	%		$789	$691	$98	14.2	%
General	23,663	22,551	1,112	4.9			313	237	76	32.1
Firm transportation	58,783	58,697	86	0.1			523	487	36	7.4
Total firm sales and transportation	121,677	118,409	3,268	2.8		(b)	1,625	1,415	210	14.8
Interruptible sales (c)	4,747	6,869	(2,122)	(30.9)			22	23	(1)	(4.3)
NYPA	36,601	29,403	7,198	24.5			2	2	—	—
Generation plants	32,653	40,073	(7,420)	(18.5)			18	17	1	5.9
Other	15,872	16,481	(609)	(3.7)			27	27	—	—
Other operating revenues (d)	—	—	—	—			36	25	11	44.0
Total	211,550	211,235	315	0.1	%		$1,730	$1,509	$221	14.6	%

(a)Revenues from gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

(b)After adjusting for variations, primarily billing days, firm gas sales and transportation volumes in the company’s service area decreased 0.9 percent in the nine months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

(c)Includes 1,700 thousand and 2,961 thousand of Dt for the 2021 and 2020 periods, respectively, which are also reflected in firm transportation and other.

(d)Other gas operating revenues generally reflect changes in the revenue decoupling mechanism and weather normalization clause current asset or regulatory liability and changes in regulatory assets and liabilities in accordance with other provisions of the company’s rate plans.

75

Operating revenues increased $221 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to an increase in revenues from the gas rate plan ($154 million) and higher gas purchased for resale expense ($59 million).

Gas purchased for resale increased $59 million in the nine months ended September 30, 2021 compared with the 2020 period due to higher unit costs ($43 million) and higher purchased volumes ($15 million).

Other operations and maintenance expenses increased $8 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher costs for pension and other postretirement benefits ($10 million) and higher surcharges for assessments and fees that are collected in revenues from customers ($7 million), offset in part by municipal infrastructure support ($10 million).

Depreciation and amortization increased $23 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher gas utility plant balances.

Taxes, other than income taxes increased $81 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to lower deferral of under-collected property taxes ($46 million), higher property taxes ($28 million) and higher state and local taxes ($6 million).

Steam

CECONY’s results of steam operations for the nine months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$393	$385	$8
Purchased power	27	19	8
Fuel	59	68	(9)
Other operations and maintenance	121	123	(2)
Depreciation and amortization	69	67	2
Taxes, other than income taxes	108	107	1
Steam operating income	$9	$1	$8

CECONY’s steam sales and deliveries for the nine months ended September 30, 2021 compared with the 2020 period were:

	Millions of Pounds Delivered						Revenues in Millions
	For the Nine Months Ended						For the Nine Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
General	396	334	62	18.6	%		$19	$17	$2	11.8	%
Apartment house	3,768	3,830	(62)	(1.6)			100	103	(3)	(2.9)
Annual power	8,888	8,462	426	5.0			256	245	11	4.5
Other operating revenues (a)	—	—	—	—			18	20	(2)	(10.0)
Total	13,052	12,626	426	3.4	%	(b)	$393	$385	$8	2.1	%

(a)Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan.

(b)After adjusting for variations, primarily weather and billing days, steam sales and deliveries decreased 3.3 percent in the nine months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $8 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to the impact of colder weather ($20 million) and higher purchased power expenses ($8 million), offset in part by lower fuel expenses ($9 million), a tax law surcharge ($6 million) and lower usage by customers due to COVID-19 pandemic ($4 million).

Purchased power expenses increased $8 million in the nine months ended September 30, 2021 compared with the 2020 period due to higher unit costs ($6 million) and purchased volumes ($2 million).

76

Fuel expenses decreased $9 million in the nine months ended September 30, 2021 compared with the 2020 period due to lower unit costs ($14 million), offset in part by higher purchased volumes from the company’s steam generating facilities ($4 million).

Other operations and maintenance expenses decreased $2 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to lower municipal infrastructure support.

Depreciation and amortization increased $2 million in the nine months ended September 30, 2021 compared with the 2020 period due to higher steam utility plant balances.

Taxes, other than income taxes increased $1 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher property taxes.

Other Income (Deductions)

Other deductions decreased $68 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to lower costs associated with components of pension and other postretirement benefits other than service cost ($60 million).

Net Interest Expense

Net interest expense increased $13 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher interest expense for long-term debt ($28 million), offset in part by lower interest accrued on the system benefit charge liability ($4 million), lower interest on short-term debt ($4 million), lower interest accrued on deferred storm costs ($2 million) and lower interest on deposits ($2 million).

Income Tax Expense

Income taxes decreased $11 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to an increase in the amortization of excess deferred federal income taxes due to the TCJA ($11 million), a higher favorable tax adjustment for the 2020 tax return primarily due to an increase in the general business tax credit ($5 million) and the absence of the amortization of excess deferred state income taxes in 2021 ($5 million), offset in part by higher income before income tax expense ($8 million) and lower flow-through tax benefits in 2021 for plant-related items ($3 million).

O&R

	For the Nine Months Ended September 30, 2021			For the Nine Months Ended September 30, 2020
(Millions of Dollars)	Electric	Gas	2021 Total	Electric	Gas	2020 Total	2021-2020 Variation
Operating revenues	$522	$177	$699	$483	$164	$647	$52
Purchased power	157	—	157	127	—	127	30
Gas purchased for resale	—	56	56	—	43	43	13
Other operations and maintenance	193	47	240	181	51	232	8
Depreciation and amortization	52	19	71	48	19	67	4
Taxes, other than income taxes	43	24	67	41	23	64	3
Operating income	$77	$31	$108	$86	$28	$114	$(6)

Electric

O&R’s results of electric operations for the nine months ended September 30, 2021 compared with the 2020 period were as follows:

77

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$522	$483	$39
Purchased power	157	127	30
Other operations and maintenance	193	181	12
Depreciation and amortization	52	48	4
Taxes, other than income taxes	43	41	2
Electric operating income	$77	$86	$(9)

O&R’s electric sales and deliveries for the nine months ended September 30, 2021 compared with the 2020 period were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Nine Months Ended						For the Nine Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
Residential/Religious (b)	1,366	1,414	(48)	(3.4	%)		$257	$247	$10	4.0	%
Commercial/Industrial	625	612	13	2.1			83	88	(5)	(5.7)
Retail choice customers	2,201	1,995	206	10.3			176	144	32	22.2
Public authorities	83	82	1	1.2			8	6	2	33.3
Other operating revenues (c)	—	—	—	—			(2)	(2)	—	—
Total	4,275	4,103	172	4.2	%	(d)	$522	$483	$39	8.1	%

(a)O&R’s New York electric delivery revenues are subject to a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. O&R’s electric sales in New Jersey are not subject to a decoupling mechanism, and as a result, changes in such volumes do impact revenues.

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

(c)Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s electric rate plan.

(d)After adjusting for weather and other variations, electric delivery volumes in O&R’s service area increased 2.4 percent in the nine months ended September 30, 2021 compared with the 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $39 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher purchased power expenses ($30 million) and higher revenues from the New York electric rate plan ($7 million).

Purchased power expenses increased $30 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher unit costs ($28 million) and higher purchased volumes ($2 million).

Other operations and maintenance expenses increased $12 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher storm-related costs.

Depreciation and amortization increased $4 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher electric utility plant balances.

Taxes, other than income taxes increased $2 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher property taxes.

Gas

O&R’s results of gas operations for the nine months ended September 30, 2021 compared with the 2020 period were as follows:

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	For the Nine Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$177	$164	$13
Gas purchased for resale	56	43	13
Other operations and maintenance	47	51	(4)
Depreciation and amortization	19	19	—
Taxes, other than income taxes	24	23	1
Gas operating income	$31	$28	$3

O&R’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, 2021 compared with the 2020 period were:

	Thousands of Dt Delivered						Revenues in Millions (a)
	For the Nine Months Ended						For the Nine Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation			September 30, 2021	September 30, 2020	Variation	Percent Variation
Residential	7,784	6,484	1,300	20.0	%		$108	$83	$25	30.1	%
General	1,729	1,443	286	19.8			19	14	5	35.7
Firm transportation	5,514	5,799	(285)	(4.9)			41	45	(4)	(8.9)
Total firm sales and transportation	15,027	13,726	1,301	9.5		(b)	168	142	26	18.3
Interruptible sales	3,002	2,723	279	10.2			4	4	—	—
Generation plants	24	24	—	—			—	—	—	—
Other	271	529	(258)	(48.8)			1	1	—	—
Other gas revenues	—	—	—	—			4	17	(13)	(76.5)
Total	18,324	17,002	1,322	7.8	%		$177	$164	$13	7.9	%

(a)Revenues from New York gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

(b)After adjusting for weather and other variations, total firm sales and transportation volumes increased 0.6 percent in the nine months ended September 30, 2021 compared with 2020 period. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $13 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to an increase in gas purchased for resale ($13 million).

Gas purchased for resale increased $13 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher purchased volumes ($11 million) and higher unit costs ($3 million).

Other operations and maintenance expenses decreased $4 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to lower spending on gas programs ($2 million), lower pension costs ($1 million) and lower uncollectible accounts ($1 million).

Taxes, other than income taxes increased $1 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher property taxes.

Income Tax Expense

Income taxes decreased $2 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to lower income before income tax expense.

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Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the nine months ended September 30, 2021 compared with the 2020 period were as follows:

	For the Nine Months Ended
(Millions of Dollars)	September 30, 2021	September 30, 2020	Variation
Operating revenues	$779	$566	$213
Gas purchased for resale	49	24	25
Other operations and maintenance	348	165	183
Depreciation and amortization	172	173	(1)
Taxes, other than income taxes	14	16	(2)
Operating income	$196	$188	$8

Operating revenues increased $213 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher revenue from renewable electric production projects ($158 million), higher wholesale revenues ($43 million), higher energy services revenues ($34 million), offset in part by net mark-to-market values ($22 million).

Gas purchased for resale increased $25 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher purchased volumes.

Other operations and maintenance expenses increased $183 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher costs from engineering, procurement and construction of renewable electric projects for customers.

Net Interest Expense

Net interest expense decreased $139 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher unrealized gains on interest rate swaps in the 2021 period.

Income Tax Expense

Income taxes increased $80 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to higher income before income tax expense ($30 million), lower income attributable to non-controlling interests ($38 million), higher state income taxes ($5 million) and the absence of a tax benefit in the 2021 period due to the change in the federal corporate income tax rate recognized for a loss carryback from the 2018 tax year to the 2013 tax year as allowed under the CARES Act that was signed into law during the first quarter of 2020 ($4 million).

Income (Loss) Attributable to Non-Controlling Interest

Income attributable to non-controlling interest decreased $152 million to a loss of $115 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to lower income attributable in the 2021 period to a tax equity investor in renewable electric projects accounted for under the HLBV method of accounting. See Note P to the Third Quarter Financial Statements.

Con Edison Transmission

Net Interest Expense

Net interest expense decreased $6 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to the repayment of an intercompany loan from the parent company from a portion of the proceeds from the substantial completion of the sale of Stagecoach. See Note R to the Third Quarter Financial Statements.

Other Income (Deductions)

Other income (deductions) decreased $256 million from $78 million of other income to $178 million of other deductions in the nine months ended September 30, 2021 compared with the 2020 period primarily due to pre-tax impairment losses of $211 million related to Con Edison Transmission's investment in Stagecoach and CET Gas foregoing AFUDC income from MVP starting January 2021 until significant construction resumes. See "Investments" in Note A to the Third Quarter Financial Statements.

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Income Tax Expense

Income taxes decreased $67 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to lower income before income tax expense ($53 million) and lower state income taxes ($16 million).

Other

Income Tax Expense

Income taxes increased $11 million in the nine months ended September 30, 2021 compared with the 2020 period primarily due to lower consolidated state income tax benefits.

Liquidity and Capital Resources

The Companies’ liquidity reflects cash flows from operating, investing and financing activities, as shown on their respective consolidated statement of cash flows and as discussed below.

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The Companies’ cash, temporary cash investments and restricted cash resulting from operating, investing and financing activities for the nine months ended September 30, 2021 and 2020 are summarized as follows:

	For the Nine Months Ended September 30,
	CECONY		O&R		Clean Energy Businesses		Con Edison Transmission		Other (a)		Con Edison (b)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020	2021	2020	2021	2020
Operating activities	$1,251	$959	$106	$82	$56	$810	$43	$(8)	$256	$(475)	$1,712	$1,368
Investing activities	(2,782)	(2,412)	(157)	(150)	(106)	(438)	608	16	—	—	(2,437)	(2,984)
Financing activities	482	543	39	50	34	(440)	(651)	(8)	(400)	568	(496)	713
Net change for the period	(1,049)	(910)	(12)	(18)	(15)	(68)	—	—	(145)	93	(1,221)	(903)
Balance at beginning of period	1,067	933	37	32	187	251	—	—	145	1	1,436	1,217
Balance at end of period (c)	$18	$23	$25	$14	$172	$183	$—	$—	$—	$94	$215	$314

(a) Includes parent company and consolidation adjustments.

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

(c) See "Reconciliation of Cash, Temporary Cash Investments and Restricted Cash" in Note A to the Third Quarter Financial Statements.

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Cash Flows from Operating Activities

The Utilities’ cash flows from operating activities primarily reflect their energy sales and deliveries and cost of operations. The volume of energy sales and deliveries is primarily affected by factors external to the Utilities, such as growth of customer demand, weather, market prices for energy and economic conditions. Measures that promote distributed energy resources, such as distributed generation, demand reduction and energy efficiency, also affect the volume of energy sales and deliveries. In addition, the decline in business activity in the Utilities’ service territory due to the COVID-19 pandemic resulted and may continue to result in a slower recovery of cash from outstanding customer accounts receivable balances and increases to the allowance for uncollectible accounts, that may further result in increases to write-offs of customer accounts. Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans, changes in delivery volumes from levels assumed when rates were approved may affect the timing of cash flows, but largely not net income. The prices at which the Utilities provide energy to their customers are determined in accordance with their rate plans. However, increases in electric and gas commodity prices, coupled with the decline in business activity due to the COVID-19 pandemic, may further contribute to a slower recovery of cash from outstanding customer accounts receivable balances and increases to the allowance for uncollectible accounts, and may result in increases to write-offs of customer accounts receivable balances. In general, changes in the Utilities’ cost of purchased power, fuel and gas may affect the timing of cash flows, but not net income, because the costs are recovered in accordance with rate plans. The Utilities’ New York rate plans allow them to defer costs resulting from a change in legislation, regulation and related actions that have taken effect during the term of the rate plans once the costs exceed a specified threshold. Increases to the allowance for uncollectible accounts related to the COVID-19 pandemic have been deferred pursuant to the legislative, regulatory and related actions provisions of their rate plans. Pursuant to their rate plans, the Utilities have recovered from customers a portion of the tax liability they will pay in the future as a result of temporary differences between the book and tax basis of assets and liabilities. These temporary differences affect the timing of cash flows, but not net income, as the Companies are required to record deferred tax assets and liabilities at the current corporate tax rate for the temporary differences. For the Utilities, credits to their customers of the net benefits of the TCJA, including the reduction of the corporate tax rate to 21 percent, decrease cash flows from operating activities. See “COVID-19 Regulatory Matters” and “Other Regulatory Matters” in Note B to the Third Quarter Financial Statements and “Coronavirus Disease 2019 (COVID-19) Impacts - Liquidity and Financing,” above.

Net income is the result of cash and non-cash (or accrual) transactions. Only cash transactions affect the Companies’ cash flows from operating activities. Principal non-cash charges or credits include depreciation, deferred income tax expense, amortizations of certain regulatory assets and liabilities, and accrued unbilled revenue. Non-cash charges or credits may also be accrued under the revenue decoupling and cost reconciliation mechanisms in the Utilities’ New York electric and gas rate plans. For Con Edison, net income for the nine months ended September 30, 2021 also included non-cash losses recognized with respect to an impairment of Con Edison Transmission’s investment in Stagecoach. See “Investments” in Note A to the Third Quarter Financial Statements.

Net cash flows from operating activities for the nine months ended September 30, 2021 for Con Edison and CECONY were $344 million and $292 million higher, respectively, than in the 2020 period. The changes in net cash flows for Con Edison and CECONY primarily reflect a change in pension and retiree benefit obligations ($56 million and $65 million, respectively), lower other receivables and other current assets ($113 million and $32 million, respectively), lower system benefit charge ($59 million and $56 million, respectively), change in pension and retiree benefit contributions ($7 million and $4 million, respectively), for Con Edison, lower cash paid for income taxes, net of refunds received ($40 million) and lower taxes receivable ($24 million), and for CECONY, a decrease in accounts receivables from affiliated companies ($101 million).

The change in net cash flows also reflects the timing of payments for and recovery of energy costs. This timing is reflected within changes to accounts receivable – customers and recoverable and refundable energy costs within other regulatory assets and liabilities and accounts payable balances.

Cash Flows Used in Investing Activities

Net cash flows used in investing activities for Con Edison and CECONY were $547 million lower and $370 million higher, respectively, for the nine months ended September 30, 2021 compared with the 2020 period. The change for Con Edison primarily reflects proceeds from the substantial completion of the sale of Stagecoach ($614 million), a decrease in non-utility construction expenditures at the Clean Energy Businesses ($125 million) and proceeds from the divestiture of renewable electric projects at the Clean Energy Businesses ($183 million), offset in part by an increase in utility construction expenditures at CECONY ($345 million) and O&R ($6 million).

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Cash Flows from Financing Activities

Net cash flows from financing activities for Con Edison and CECONY were $1,209 million and $61 million lower, respectively, in the nine months ended September 30, 2021 compared with the 2020 period.

In June 2021, Con Edison issued 10,100,000 shares of its common stock resulting in net proceeds of approximately $775 million, after issuance expenses. The net proceeds from the sale of the common shares were invested by Con Edison in CECONY, for funding of its construction expenditures and for its other general corporate purposes. See Note C to the Third Quarter Financial Statements.

In May 2021, Con Edison redeemed at maturity $500 million of 2.00 percent 5-year debentures. See Note C to the Third Quarter Financial Statements.

During the first quarter of 2021, Con Edison optionally prepaid the remaining $675 million outstanding under a February 2019 term loan prior to its maturity in June 2021.

In July 2020, Con Edison borrowed $820 million pursuant to an April 2020 credit agreement that was amended in June 2020 (as amended, the Supplemental Credit Agreement). Con Edison used the proceeds from the borrowing for general corporate purposes, including repayment of short-term debt bearing interest at variable rates.

In January 2020, Con Edison issued 1,050,000 shares of its common stock for $88 million upon physical settlement of the remaining shares subject to its May 2019 forward sale agreement.

In June 2021, CECONY redeemed at maturity $640 million of floating rate 3-year debentures. See Note C to the Third Quarter Financial Statements.

In June 2021, CECONY issued $750 million aggregate principal amount of 2.40 percent debentures, due 2031, the net proceeds from the sale of which were used to redeem at maturity its $640 million floating rate 3-year debentures and for other general corporate purposes. In June 2021 CECONY also issued $750 million aggregate principal amount of 3.60 percent debentures, due 2061, the net proceeds from the sale of which will be used to pay or reimburse the payment of, in whole or in part, existing and new qualifying eligible green expenditures, such as energy efficiency and clean transportation expenditures, that include those funded on or after January 1, 2021 until the maturity date of the debentures. Pending the allocation of the net proceeds to finance or refinance eligible green expenditures, CECONY used the net proceeds for repayment of short-term debt and temporarily placed the remaining net proceeds in short-term interest-bearing instruments. See Note C to the Third Quarter Financial Statements.

In June 2020, CECONY redeemed at maturity $350 million of 4.45 percent 10-year debentures.

In March 2020, CECONY issued $600 million aggregate principal amount of 3.35 percent debentures, due 2030 and $1,000 million aggregate principal amount of 3.95 percent debentures, due 2050, the net proceeds from the sale of which will be used to pay or reimburse the payment of, in whole or in part, existing and new qualifying eligible green expenditures, such as energy efficiency and clean transportation expenditures, that include those funded on or after January 1, 2018 until the maturity date of each series of the debentures. Pending the allocation of the net proceeds to finance or refinance eligible green expenditures, CECONY used the net proceeds for repayment of short-term debt and temporarily placed the remaining net proceeds in short-term interest-bearing instruments.

In September 2021, O&R agreed to issue in December 2021 $45 million aggregate principal amount of 2.31 percent debentures, due 2031 and $30 million aggregate principal amount of 3.17 percent debentures, due 2051.

In September 2020, O&R issued $35 million aggregate principal amount of 2.02 percent debentures, due 2030 and $40 million aggregate principal amount of 3.24 percent debentures, due 2050.

In March 2021, a subsidiary of the Clean Energy Businesses agreed to issue $229 million aggregate principal amount of 3.77 percent senior notes, due 2046, secured by equity interests in CED Nevada Virginia, all of which had been issued at September 30, 2021. See Notes C and D to the Third Quarter Financial Statements.

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In February 2021, a subsidiary of the Clean Energy Businesses borrowed $250 million at a variable rate, due 2028, secured by equity interests in four of the company’s solar electric production projects, the interest rate for which was swapped to a fixed rate of 3.39 percent. See Note C to the Third Quarter Financial Statements.

In February 2021, a subsidiary of the Clean Energy Businesses entered into an agreement with a tax equity investor for the financing of a portfolio of three of the Clean Energy Businesses’ solar electric production projects (CED Nevada Virginia). Under the financing, the tax equity investor acquired a noncontrolling interest in the portfolio and will receive a percentage of earnings, tax attributes and cash flows. As of September 30, 2021, the tax equity investor fully funded its $263 million financing obligation. The Clean Energy Businesses will continue to consolidate this entity and will report the noncontrolling tax equity investor’s interest in the tax equity arrangement. See Notes C and P to the Third Quarter Financial Statements.

Con Edison’s cash flows from financing for the nine months ended September 30, 2021 and 2020 also reflect the proceeds, and reduction in cash used for reinvested dividends, resulting from the issuance of common shares under the company’s dividend reinvestment, stock purchase and long-term incentive plans of $82 million and $79 million, respectively.

Cash flows used in financing activities of the Companies also reflect commercial paper issuances and repayments. The commercial paper amounts outstanding at September 30, 2021 and 2020 and the average daily balances for the nine months ended September 30, 2021 and 2020 for Con Edison and CECONY were as follows:

	2021				2020
(Millions of Dollars, except Weighted Average Yield)	Outstanding at September 30,		Daily average		Outstanding at September 30,		Daily average
Con Edison	$1,036		$1,294		$1,009		$1,027
CECONY	$942		$1,194		$991		$633
Weighted average yield	0.1	%	0.2	%	0.2	%	1.2	%

Capital Requirements and Resources

During the third quarter of 2021, Con Edison increased its estimate for capital requirements in 2021 from $6,015 million to $6,065 million. The increase reflects additional investments by the Clean Energy Businesses. During the first quarter of 2021, Con Edison increased its estimates for capital requirements for 2021, 2022 and 2023 from $5,985 million to $6,015 million, $4,380 million to $4,644 million and $5,137 million to $5,385 million, respectively. The increase reflects additional investments for the Reliable Clean City (RCC) projects approved by the NYSPSC in April 2021. See “CECONY” – “Electric” – “Electric Supply,” above. The company plans to meet its capital requirements for 2021 through 2023, through internally-generated funds and the issuance of long-term debt and common equity. The company's plans include the issuance of between $1,900 million and $2,600 million of long-term debt, including for maturing securities, primarily at the Utilities, in 2021 and approximately $1,400 million in aggregate of long-term debt at the Utilities during 2022 and 2023. The planned debt issuance is in addition to the issuance of long-term debt secured by the Clean Energy Businesses’ renewable electric production projects. The company's plans also include the issuance of up to $800 million of common equity in 2021 and approximately $700 million in aggregate of common equity during 2022 and 2023, in addition to equity under its dividend reinvestment, employee stock purchase and long-term incentive plans. See Note C to the Third Quarter Financial Statements and “Liquidity and Capital Resources - Cash Flows from Financing Activities,” above.

Capital Resources

For each of the Companies, the common equity ratio at September 30, 2021 and December 31, 2020 was:

	Common Equity Ratio (Percent of total capitalization)
	September 30, 2021	December 31, 2020
Con Edison	48.3	48.3
CECONY	47.9	47.9

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Assets, Liabilities and Equity

The Companies' assets, liabilities, and equity at September 30, 2021 and December 31, 2020 are summarized as follows. 

	CECONY		O&R		Clean Energy  Businesses		Con Edison Transmission		Other (a)		Con Edison (b)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020	2021	2020	2021	2020
ASSETS
Current assets	$4,349	$4,407	$306	$277	$510	$485	$8	$42	$(77)	$90	$5,096	$5,301
Investments	597	541	27	26	7	—	454	1,256	(7)	(7)	1,078	1,816
Net plant	40,985	39,554	2,550	2,469	4,396	4,515	17	17	(1)	—	47,947	46,555
Other noncurrent assets	6,247	6,465	461	475	1,691	1,848	14	33	404	402	8,817	9,223
Total Assets	$52,178	$50,967	$3,344	$3,247	$6,604	$6,848	$493	$1,348	$319	$485	$62,938	$62,895
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	$4,127	$5,247	$420	$356	$990	$1,330	$92	$111	$(374)	$310	$5,255	$7,354
Noncurrent liabilities	14,194	14,722	1,168	1,191	121	211	(15)	28	(3)	(58)	15,465	16,094
Long-term debt	17,637	16,149	893	893	2,664	2,776	—	500	647	64	21,841	20,382
Equity	16,220	14,849	863	807	2,829	2,531	416	709	49	169	20,377	19,065
Total Liabilities and Equity	$52,178	$50,967	$3,344	$3,247	$6,604	$6,848	$493	$1,348	$319	$485	$62,938	$62,895

(a) Includes parent company and consolidation adjustments.

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

CECONY

Current assets at September 30, 2021 were $58 million lower than at December 31, 2020. The change in current assets primarily reflects a decrease in cash and temporary cash investments ($1,049 million), primarily due to the July 2021 payment of New York City semi-annual property taxes. The decrease is offset in part by an increase in prepayments reflecting primarily the July 2021 payment of New York City semi-annual property taxes, offset in part by three months of amortization, while the December 2020 balance reflects the amortization of the entire previous semi-annual payment ($555 million), an increase in accounts receivables, less allowance for uncollectible accounts ($221 million) (see “COVID-19 Regulatory Matters” in Note B to the Third Quarter Financial Statements and “Coronavirus Disease 2019 (COVID-19) Impacts - Accounting Considerations” and “Liquidity and Financing,” above) and an increase in the fair value of short-term derivative assets ($213 million).

Investments at September 30, 2021 were $56 million higher than at December 31, 2020. The change in investments primarily reflects an increase in supplemental retirement income plan assets. See Note E to the Third Quarter Financial Statements.

Net plant at September 30, 2021 was $1,431 million higher than at December 31, 2020. The change in net plant primarily reflects an increase in electric ($1,040 million), gas ($983 million), steam ($77 million) and general ($192 million) plant balances, offset in part by an increase in accumulated depreciation ($664 million) and a decrease in construction work in progress ($197 million).

Other noncurrent assets at September 30, 2021 were $218 million lower than at December 31, 2020. The change in other noncurrent assets primarily reflects a decrease in the regulatory asset for unrecognized pension and other postretirement costs to reflect the final actuarial valuation, as measured at December 31, 2020, of the pension and other retiree benefit plans in accordance with the accounting rules for retirement benefits ($671 million). See Notes B, E and F to the Third Quarter Financial Statements. The change in the regulatory asset also reflects the year's amortization of accounting costs. This decrease is offset in part by an increase in the regulatory assets for deferrals for increased costs related to the COVID-19 pandemic ($156 million), deferred pension and other postretirement benefits ($110 million), deferred storm costs ($72 million), revenue taxes ($27 million) and deferred derivative losses ($13 million). See “Other Regulatory Matters” in Note B and Note G to the Third Quarter Financial Statements. This decrease is also offset in part by an increase in the fair value of long-term derivative assets ($78 million).

Current liabilities at September 30, 2021 were $1,120 million lower than at December 31, 2020. The change in current liabilities primarily reflects decreases in notes payable ($718 million), long-term debt due within one year

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($640 million), accounts payable ($131 million), offset in part by an increase in the regulatory liability for deferred derivative gains ($416 million).

Noncurrent liabilities at September 30, 2021 were $528 million lower than at December 31, 2020. The change in noncurrent liabilities primarily reflects a decrease in the liability for pension and retiree benefits ($764 million) that primarily reflects the final actuarial valuation, as measured at December 31, 2020, of the plans in accordance with the accounting rules for retirement benefits. See Notes E and F to the Third Quarter Financial Statements. The change also reflects a decrease in the regulatory liability for future income tax ($166 million). These decreases are offset in part by a change in deferred income taxes and unamortized investment tax credits ($359 million) that primarily reflects accelerated tax depreciation, repair deductions and the prepayment of New York City property taxes. See Note J to the Third Quarter Financial Statements.

Long-term debt at September 30, 2021 was $1,488 million higher than at December 31, 2020. The change in long-term debt primarily reflects the June 2021 issuance of $1,500 million of debentures. See "Liquidity and Capital Resources - Cash Flows From Financing Activities" above and Note C to the Third Quarter Financial Statements.

Equity at September 30, 2021 was $1,371 million higher than at December 31, 2020. The change in equity primarily reflects capital contributions from parent ($1,101 million) in 2021 and net income for the nine months ended September 30, 2021 ($1,011 million), offset in part by common stock dividends to parent ($741 million) in 2021.

O&R

Current assets at September 30, 2021 were $29 million higher than at December 31, 2020. The change in current assets primarily reflects increases in other receivables, less allowance for uncollectible accounts ($11 million) and accounts receivables, less allowance for uncollectible accounts ($11 million).

Net plant at September 30, 2021 was $81 million higher than at December 31, 2020. The change in net plant primarily reflects an increase in electric ($91 million), gas ($39 million), and general ($19 million) plant balances, offset in part by an increase in accumulated depreciation ($55 million) and a decrease in construction work in progress ($13 million).

Other noncurrent assets at September 30, 2021 were $14 million lower than at December 31, 2020. The change in other noncurrent assets primarily reflects a decrease in the regulatory asset for unrecognized pension and other postretirement costs to reflect the final actuarial valuation, as measured at December 31, 2020, of the pension and other retiree benefit plans in accordance with the accounting rules for retirement benefits ($43 million). See Notes B, E and F to the Third Quarter Financial Statements. The change in the regulatory asset also reflects the year's amortization of accounting costs. This decrease is offset in part by an increase in the regulatory asset for deferred pension and other postretirement benefits ($13 million) and an increase in deferred storm costs ($10 million).

Current liabilities at September 30, 2021 were $64 million higher than at December 31, 2020. The change in current liabilities primarily reflects higher notes payable ($43 million), an increase in the regulatory liability for deferred derivative gains ($27 million), offset in part by lower accounts payables ($9 million).

Noncurrent liabilities at September 30, 2021 were $23 million lower than at December 31, 2020. The change in noncurrent liabilities primarily reflects a decrease in the liability for pension and retiree benefits ($69 million), offset in part by deferred income taxes and unamortized investment tax credits ($15 million), primarily due to accelerated tax depreciation and repair deductions, an increase in the regulatory liability for long-term deferred derivative gains ($8 million) and deferred other retiree benefit plans rate ($4 million), and an increase in other deferred credits ($16 million).

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Equity at September 30, 2021 was $56 million higher than at December 31, 2020. The change in equity primarily reflects net income for the nine months ended September 30, 2021 ($53 million), capital contributions from parent ($35 million) in 2021 and an increase in other comprehensive income ($7 million) offset in part by common stock dividends to parent ($39 million) in 2021.

Clean Energy Businesses

Current assets at September 30, 2021 were $25 million higher than at December 31, 2020. The change in current assets primarily reflects an increase in accrued unbilled revenue ($74 million), offset in part by a decrease in restricted cash ($15 million) and a decrease in other currents assets ($35 million).

Investments at September 30, 2021 were $7 million higher than at December 31, 2020. The change in investments primarily reflects a tax equity investment.

Net plant at September 30, 2021 was $119 million lower than at December 31, 2020. The change in net plant primarily reflects the divestiture of renewable electric projects. See Note R to the Third Quarter Financial Statements.

Other noncurrent assets at September 30, 2021 were $157 million lower than at December 31, 2020. The change in other noncurrent assets primarily reflects the divestiture of renewable electric projects. See Note R to the Third Quarter Financial Statements.

Current liabilities at September 30, 2021 were $340 million lower than at December 31, 2020. The change in current liabilities primarily reflects new borrowing offset in part by a decrease in borrowings under a term loan. See Note D to the Third Quarter Financial Statements.

Noncurrent liabilities at September 30, 2021 were $90 million lower than at December 31, 2020. The change in noncurrent liabilities primarily reflects the change in the fair value of derivative liabilities and the change in deferred taxes.

Long-term debt at September 30, 2021 was $112 million lower than at December 31, 2020. The change in long-term debt primarily reflects the repayment of an intercompany loan from the parent company ($375 million), offset in part by a net increase in project debt ($464 million). See Note C to the Third Quarter Financial Statements.

Equity at September 30, 2021 was $298 million higher than at December 31, 2020. The change in equity primarily reflects an increase in net income for the nine months ended September 30, 2021 ($223 million) and a noncontrolling tax equity interest ($122 million) (see Note P to the Third Quarter Financial Statements), offset in part by common stock dividends to parent ($48 million) in 2021.

Con Edison Transmission

Current assets at September 30, 2021 were $34 million lower than at December 31, 2020. The change in current assets primarily reflects the agreement between Crestwood and a subsidiary of CET Gas that provides for payments from Crestwood to the subsidiary of CET Gas for shortfalls in meeting certain earnings growth performance targets. Payments totaled $57 million ($19 million of which was paid in the first quarter 2021 and was recorded as a receivable by CET Gas in March 2020, and the remainder of which, plus interest was paid by Crestwood in July 2021). See "Con Edison Transmission - CET Gas," below.

Investments at September 30, 2021 were $802 million lower than at December 31, 2020. The decrease in investments primarily reflects the substantial completion of the sale of Stagecoach ($828 million), offset in part by additional investment in and income from NY Transco ($27 million). See "Investments" in Note A and Note R to the Third Quarter Financial Statements.

Other noncurrent assets were $19 million lower than at December 31, 2020. The change in noncurrent assets primarily reflects a reduction in accounts receivable due to the noncurrent portion of the $57 million payment from Crestwood described above.

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Current liabilities at September 30, 2021 were $19 million lower than at December 31, 2020. The change in current liabilities primarily reflects the repayment of short-term borrowings under an intercompany capital funding facility with a portion of the proceeds from the substantial completion of the sale of Stagecoach. See Note R to the Third Quarter Financial Statements.

Noncurrent liabilities at September 30, 2021 were $43 million lower than at December 31, 2020. The change in noncurrent liabilities reflects primarily a decrease in deferred income taxes and unamortized investment tax credits that reflects primarily timing differences associated with investments in partnerships and the tax loss on the substantial completion of the sale of Stagecoach. See "Investments" in Note A and Note R to the Third Quarter Financial Statements.

Long-term debt at September 30, 2021 was $500 million lower than at December 31, 2020. The change in long-term debt reflects the repayment of a $500 million intercompany loan from the parent company.

Equity at September 30, 2021 was $293 million lower than at December 31, 2020. The change in equity primarily reflects net loss for the nine months ended September 30, 2021 ($142 million) and a reduction to retained earnings due to a dividend paid to CEI ($150 million).

Off-Balance Sheet Arrangements

At September 30, 2021, none of the Companies’ transactions, agreements or other contractual arrangements met the SEC definition of off-balance sheet arrangements.

Regulatory Matters

For information about the Utilities’ regulatory matters, see Note B to the Third Quarter Financial Statements.

Environmental Matters

In July 2021, a feeder failure led to the discharge of thousands of gallons of dielectric fluid from a street manhole in New Rochelle, New York. Dielectric fluid reached nearby streets, properties and the New Rochelle Harbor. CECONY, the U.S. Coast Guard, the New York State Department of Environmental Conservation and other agencies responded to the incident. The company stopped the feeder leak on the same day that the discharge occurred and has substantially completed the spill recovery operations. In coordination with federal and state regulators, CECONY is evaluating certain shoreline areas for the potential presence of residual dielectric fluid and the extent to which additional cleaning in such areas may be necessary. In addition, the company has received third-party damage claims. The costs associated with this matter are not expected to have a material adverse effect on the company’s financial condition, results of operations or liquidity. In connection with the incident, the company may incur monetary sanctions of more than $0.3 million for violations of certain provisions regulating the discharge of materials into, and for the protection of, the environment.

For additional information about the Companies’ environmental matters, see Note G to the Third Quarter Financial Statements. 

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Clean Energy Businesses

The following table provides information about the Clean Energy Businesses' renewable electric production projects that are in operation and/or in construction at September 30, 2021:

Project Name	Generating Capacity (MW AC)	Power Purchase Agreement (PPA) Term (In Years) (a)	Actual/Expected In-Service Date (b)	State	PPA Counterparty (c)
Utility Scale
Solar
PJM assets	73	(d)	2011/2013	New Jersey/Pennsylvania	Various
New England assets	24	Various	2011/2017	Massachusetts/Rhode Island	Various
California Solar (e)	110	25	2012/2013	California	PG&E
Mesquite Solar 1 (e)	165	20	2013	Arizona	PG&E
Copper Mountain Solar 2 (e)	150	25	2013/2015	Nevada	PG&E
Copper Mountain Solar 3 (e)	255	20	2014/2015	Nevada	SCPPA
California Solar 2 (e)	80	20	2014/2016	California	SCE/PG&E
Texas Solar 4 (e)	40	25	2014	Texas	City of San Antonio
Texas Solar 5 (e)	100	25	2015	Texas	City of San Antonio
Texas Solar 7 (e)	112	25	2016	Texas	City of San Antonio
California Solar 3 (e)	110	20	2016/2017	California	SCE/PG&E
Upton Solar (e)	158	25	2017	Texas	City of Austin
California Solar 4 (e)	240	20	2017/2018	California	SCE
Copper Mountain Solar 1 (e)	58	12	2018	Nevada	PG&E
Copper Mountain Solar 4 (e) (f)	94	20	2018	Nevada	SCE
Mesquite Solar 2 (e) (f)	100	18	2018	Arizona	SCE
Mesquite Solar 3 (e) (f)	150	23	2018	Arizona	WAPA (U.S. Navy)
Great Valley Solar (e) (f)	200	17	2018	California	MCE/SMUD/PG&E/SCE
Water Strider Solar (e) (f) (g)	80	20	2021	Virginia	VEPCO
Battle Mountain Solar/Battery Energy Storage System (e) (f) (g)	101	25	2021	Nevada	SPP
Copper Mountain Solar 5 (e) (f) (g)	250	25	2021	Nevada	NPC
Other	26	Various	Various	Various	Various
Total Solar	2,676
Wind
Broken Bow II (e)	75	25	2014	Nebraska	NPPD
Wind Holdings (e)	180	Various	Various	South Dakota/ Montana	NWE/Basin Electric
Adams Rose Wind (e)	23	7	2016	Minnesota	Dairyland
Other	34	Various	Various	Various	Various
Total Wind	312
Total MW (AC) in Operation	2,988
Total MW (AC) in Construction	16
Total MW (AC) Utility Scale	3,004
Behind the Meter
Total MW (AC) in Operation	62
Total MW (AC) in Construction	10
Total MW Behind the Meter	72

(a)Represents PPA contractual term or remaining term from the date of acquisition.

(b)Represents Actual/Expected In-Service Date or date of acquisition.

(c)PPA Counterparties include: Pacific Gas and Electric Company (PG&E), Southern California Public Power Authority (SCPPA), Southern California Edison Company (SCE), Western Area Power Administration (WAPA), Marin Clean Energy (MCE), Sacramento Municipal Utility District (SMUD), Nebraska Public Power District (NPPD), NorthWestern Energy (NWE), Virginia Electric Power Company (VEPCO), Sierra Pacific Power (SPP), and Nevada Power Company (NPC).

(d)Solar renewable energy credit hedges are in place, in lieu of PPAs, through 2025.

(e)Project has been pledged as security for project debt financing.

(f)Projects are financed with tax equity. See Note P to the Third Quarter Financial Statements.

(g)Battle Mountain, Water Strider, and Copper Mountain 5 are a portfolio of three solar electric production projects referred to as CED Nevada Virginia. See Notes C, D and P to the Third Quarter Financial Statements.

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Renewable Electric Generation

Renewable electric production volumes from utility scale assets for the three and nine months ended September 30, 2021 compared with the 2020 period were:

	Millions of kWh
	For the Three Months Ended				For the Nine Months Ended
Description	September 30, 2021	September 30, 2020	Variation	Percent Variation	September 30, 2021	September 30, 2020	Variation	Percent Variation
Renewable electric production projects
Solar	1,932	1,667	265	15.9%	4,998	4,606	392	8.5%
Wind	257	303	(46)	(15.2)%	978	1,042	(64)	(6.1%)
Total	2,189	1,970	219	11.1%	5,976	5,648	328	5.8%

Con Edison Transmission

CET Gas

In May 2021, a subsidiary of CET Gas entered into a purchase and sale agreement pursuant to which CET Gas and Crestwood agreed to sell their combined interests in Stagecoach to a subsidiary of Kinder Morgan Inc. for a total of $1,225 million, subject to certain adjustments, of which $612.5 million will be Con Edison's portion for its 50 percent interest, subject to closing adjustments. The purchase and sale agreement contemplates a two-stage closing, the first of which was completed in July 2021 for a sale price of $1,195 million, of which $614 million, including working capital, was attributed to CET Gas. The second closing for the remaining $30 million, of which $15 million will be attributed to CET Gas, subject to closing adjustments, is to occur following approval by the NYSPSC, which is expected later this year or during the first quarter of 2022, subject to customary closing conditions. See Note R to the Third Quarter Financial Statements.

As a result of information made available to Stagecoach as part of the sale process, Stagecoach performed impairment tests that resulted in Stagecoach recording impairment charges of $414 million for the nine months ended September 30, 2021. Accordingly, Con Edison recorded pre-tax impairment losses on its 50 percent interest in Stagecoach of $211 million ($147 million after-tax), including working capital and transaction cost adjustments, within "Investment income/(loss)" on Con Edison's consolidated income statement for the nine months ended September 30, 2021. These charges reduced the carrying value of Con Edison’s investment in Stagecoach to $630 million at June 30, 2021. See "Investments" in Note A to the Third Quarter Financial Statements.

In May 2021, the operator of the Mountain Valley Pipeline, which is being constructed by a joint venture in which CET Gas owns a 10.6 percent interest (that is expected to be reduced to 8.5 percent based on the current project cost estimate and CET Gas’ previous capping of its cash contributions to the joint venture) indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is now targeting an in-service date for the project of summer 2022 at an overall project cost of approximately $6,200 million excluding allowance for funds used during construction. For the year ended December 31, 2020, CET Gas recorded a pre-tax impairment loss of $320 million ($223 million after-tax) that reduced the carrying value of its investment in Mountain Valley Pipeline LLC from $662 million to $342 million. At September 30, 2021, CET Gas’ cash contributions to the joint venture amounted to $530 million.

CET Gas and CECONY own 71.2 percent and 28.8 percent interests, respectively, in Honeoye, which operates a gas storage facility in upstate New York. CET Gas and CECONY are in the process of considering strategic alternatives regarding their interests in Honeoye. At September 30, 2021, the consolidated carrying value of CET Gas’ and CECONY’s investments in Honeoye was $25 million.

Financial and Commodity Market Risks

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

Interest Rate Risk

The Companies’ interest rate risk primarily relates to new debt financing needed to fund capital requirements, including the construction expenditures of the Utilities and maturing debt securities, and variable-rate debt. Con

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Edison and its subsidiaries manage interest rate risk through the issuance of mostly fixed-rate debt with varying maturities and through opportunistic refinancing of debt. The Clean Energy Businesses use interest rate swaps to exchange variable-rate project financed debt for a fixed interest rate. See Note N to the Third Quarter Financial Statements. Con Edison and CECONY estimate that at September 30, 2021, a 10 percent increase in interest rates applicable to its variable rate debt would result in an immaterial increase in annual interest expense. Under CECONY’s current electric, gas and steam rate plans, variations in actual variable rate tax-exempt debt interest expense, including costs associated with the refinancing of the variable-rate tax-exempt debt, are reconciled to levels reflected in rates.

Commodity Price Risk

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

Con Edison estimates that, as of September 30, 2021, a 10 percent decline in market prices would result in a decline in fair value of $149 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $139 million is for CECONY and $10 million is for O&R. Con Edison expects that any such change in fair value would be largely offset by directionally opposite changes in the cost of the electricity and gas purchased. In accordance with provisions approved by state regulators, the Utilities generally recover from customers the costs they incur for energy purchased for their customers, including gains and losses on certain derivative instruments used to hedge energy purchased and related costs. However, increases in electric and gas commodity prices may contribute to a slower recovery of cash from outstanding customer accounts receivable balances and increases to the allowance for uncollectible accounts, and may result in increases to write-offs of customer accounts receivable balances.

The Clean Energy Businesses use a value-at-risk (VaR) model to assess the market price risk of their portfolio of electricity and gas commodity fixed-price purchase and sales commitments, physical forward contracts, generating assets and commodity derivative instruments. VaR represents the potential change in fair value of the portfolio due to changes in market prices, for a specified time period and confidence level. These businesses estimate VaR across their portfolio using a delta-normal variance/covariance model with a 95 percent confidence level, compare the measured VaR results against performance due to actual prices and stress test the portfolio each quarter using an assumed 30 percent price change from forecast. Since the VaR calculation involves complex methodologies and estimates and assumptions that are based on past experience, it is not necessarily indicative of future results. VaR for the portfolio, assuming a one-day holding period, for the nine months ended September 30, 2021 and the year ended December 31, 2020, respectively, was as follows:

95% Confidence Level, One-Day Holding Period	September 30, 2021	December 31, 2020
	(Millions of Dollars)
Average for the period	$—	$—
High	2	—
Low	—	—

Investment Risk

The Companies’ investment risk relates to the investment of plan assets for their pension and other postretirement benefit plans. Con Edison's investment risk also relates to the investments of Con Edison Transmission that are accounted for under the equity method. See "Investments" in Note A to the Third Quarter Financial Statements.

The Companies’ current investment policy for pension plan assets includes investment targets of 45 to 55 percent equity securities, 33 to 43 percent debt securities and 10 to 14 percent real estate. At September 30, 2021, the pension plan investments consisted of 50 percent equity securities, 39 percent debt securities and 11 percent real estate.

For the Utilities’ pension and other postretirement benefit plans, regulatory accounting treatment is generally applied in accordance with the accounting rules for regulated operations. In accordance with the Statement of Policy issued by the NYSPSC and its current electric, gas and steam rate plans, CECONY defers for payment to or recovery from customers the difference between the pension and other postretirement benefit expenses and the amounts for such expenses reflected in rates. O&R also defers such difference pursuant to its New York rate plans.

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Material Contingencies

For information concerning potential liabilities arising from the Companies’ material contingencies, see "Other Regulatory Matters" in Note B and Notes G and H to the Third Quarter Financial Statements.

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Item 3: Quantitative and Qualitative Disclosures About Market Risk

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

Item 4: Controls and Procedures

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

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

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Part II Other Information

Item 1: Legal Proceedings

For information about certain legal proceedings affecting the Companies, see "Other Regulatory Matters" in Note B and Notes G and H to the financial statements in Part I, Item 1 of this report and "Environmental Matters" in Part I, Item 2 of this report, which information is incorporated herein by reference.

Item 1A: Risk Factors

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

Item 6: Exhibits

Con Edison

Exhibit 31.1.1	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer.
Exhibit 31.1.2	Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer.
Exhibit 32.1.1	Section 1350 Certifications – Chief Executive Officer.
Exhibit 32.1.2	Section 1350 Certifications – Chief Financial Officer.
Exhibit 101.INS	XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
Exhibit 101.SCH	XBRL Taxonomy Extension Schema.
Exhibit 101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
Exhibit 101.DEF	XBRL Taxonomy Extension Definition Linkbase.
Exhibit 101.LAB	XBRL Taxonomy Extension Label Linkbase.
Exhibit 101.PRE	XBRL Taxonomy Extension Presentation Linkbase.
Exhibit 104	Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document.

CECONY

Exhibit 31.2.1	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer.
Exhibit 31.2.2	Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer.
Exhibit 32.2.1	Section 1350 Certifications – Chief Executive Officer.
Exhibit 32.2.2	Section 1350 Certifications – Chief Financial Officer.
Exhibit 101.INS	XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
Exhibit 101.SCH	XBRL Taxonomy Extension Schema.
Exhibit 101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
Exhibit 101.DEF	XBRL Taxonomy Extension Definition Linkbase.
Exhibit 101.LAB	XBRL Taxonomy Extension Label Linkbase.
Exhibit 101.PRE	XBRL Taxonomy Extension Presentation Linkbase.
Exhibit 104	Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document.

Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, instruments defining the rights of holders of long-term debt of Con Edison’s subsidiaries other than CECONY, the total amount of which does not exceed ten percent of the total assets of Con Edison and its subsidiaries on a consolidated basis, are not filed as exhibits to Con Edison’s Form 10-K or Form 10-Q. Con Edison agrees to furnish to the SEC upon request a copy of any such instrument.

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Signatures

Pursuant to the requirements of the Securities Exchange Act of 1934, each Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	Consolidated Edison, Inc.
	Consolidated Edison Company of New York, Inc.
Date: November 4, 2021	By	/s/ Robert Hoglund
		Robert Hoglund Senior Vice President, Chief Financial Officer and Duly Authorized Officer

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EX-31.1.1

Exhibit 31.1.1

CERTIFICATIONS

I, Timothy P. Cawley, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021 of Consolidated Edison, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 4, 2021

/s/ Timothy P. Cawley

Timothy P. Cawley

 President and Chief Executive Officer

EX-31.1.2

Exhibit 31.1.2

CERTIFICATIONS

I, Robert Hoglund, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021 of Consolidated Edison, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 4, 2021

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

EX-31.2.1

Exhibit 31.2.1

CERTIFICATIONS

I, Timothy P. Cawley, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021 of Consolidated Edison Company of New York, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 4, 2021

/s/ Timothy P. Cawley

Timothy P. Cawley

Chief Executive Officer

EX-31.2.2

Exhibit 31.2.2

CERTIFICATIONS

I, Robert Hoglund, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021 of Consolidated Edison Company of New York, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 4, 2021

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

EX-32.1.1

Exhibit 32.1.1

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

I, Timothy P. Cawley, the Chief Executive Officer of Consolidated Edison, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021, which this statement accompanies, (the “Form 10-Q”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)) and that the information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Timothy P. Cawley

Timothy P. Cawley

Date: November 4, 2021

EX-32.1.2

Exhibit 32.1.2

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

I, Robert Hoglund, the Chief Financial Officer of Consolidated Edison, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021, which this statement accompanies, (the “Form 10-Q”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)) and that the information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Robert Hoglund

Robert Hoglund

Date: November 4, 2021

EX-32.2.1

Exhibit 32.2.1

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

I, Timothy P. Cawley, the Chief Executive Officer of Consolidated Edison Company of New York, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021, which this statement accompanies, (the “Form 10-Q”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)) and that the information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Timothy P. Cawley

Timothy P. Cawley

Date: November 4, 2021

EX-32.2.2

Exhibit 32.2.2

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

I, Robert Hoglund, the Chief Financial Officer of Consolidated Edison Company of New York, Inc. (the “Company”) certify that the Company’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2021, which this statement accompanies, (the “Form 10-Q”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m or 78o(d)) and that the information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Robert Hoglund

Robert Hoglund

Date: November 4, 2021

XML

Cover Page - shares	9 Months Ended
	Sep. 30, 2021	Oct. 31, 2021
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2021
Document Transition Report	false
Entity File Number	1-14514
Entity Registrant Name	Consolidated Edison, Inc.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-3965100
Entity Address, Address Line One	4 Irving Place,
Entity Address, City or Town	New York,
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	10003
City Area Code	(212)
Local Phone Number	460-4600
Title of 12(b) Security	Common Shares ($.10 par value)
Trading Symbol	ED
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		353,748,736
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q3
Entity Central Index Key	0001047862
Current Fiscal Year End Date	--12-31
CECONY
Document Information [Line Items]
Entity File Number	1-1217
Entity Registrant Name	Consolidated Edison Company of New York, Inc.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-5009340
Entity Address, Address Line One	4 Irving Place,
Entity Address, City or Town	New York,
Entity Address, State or Province	NY
Entity Address, Postal Zip Code	10003
City Area Code	(212)
Local Phone Number	460-4600
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q3
Entity Central Index Key	0000023632
Current Fiscal Year End Date	--12-31

XML

CONSOLIDATED INCOME STATEMENT (UNAUDITED) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
OPERATING REVENUES
Total operating revenues	$ 3,613	$ 3,333	$ 10,261	$ 9,286
OPERATING EXPENSES
Depreciation and amortization	512	482	1,511	1,428
Taxes, other than income taxes	727	673	2,103	1,915
TOTAL OPERATING EXPENSES	2,763	2,473	8,132	7,139
OPERATING INCOME	850	860	2,129	2,147
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	5	27	(180)	78
Other income	5	8	19	15
Allowance for equity funds used during construction	5	2	15	12
Other deductions	(37)	(50)	(113)	(177)
TOTAL OTHER INCOME (DEDUCTIONS)	(22)	(13)	(259)	(72)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	828	847	1,870	2,075
INTEREST EXPENSE
Interest on long-term debt	235	227	693	685
Other interest	(2)	4	(15)	122
Allowance for borrowed funds used during construction	(1)	(5)	(9)	(10)
NET INTEREST EXPENSE	232	226	669	797
INCOME BEFORE INCOME TAX EXPENSE	596	621	1,201	1,278
INCOME TAX EXPENSE	127	119	194	183
NET INCOME	469	502	1,007	1,095
Income (loss) attributable to non-controlling interest	(69)	9	(115)	37
NET INCOME	$ 538	$ 493	$ 1,122	$ 1,058
Net income per common share - basic (dollars per share)	$ 1.52	$ 1.47	$ 3.23	$ 3.17
Net income per common share - diluted (dollars per share)	$ 1.52	$ 1.47	$ 3.23	$ 3.16
AVERAGE NUMBER OF SHARES OUTSTANDING-BASIC (shares)	353.4	334.5	346.8	334.1
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (shares)	354.1	335.4	347.5	335.0
Subsidiaries
OPERATING REVENUES
Total operating revenues	$ 3,092	$ 2,872	$ 8,784	$ 8,072
OPERATING EXPENSES
Depreciation and amortization	429	401	1,267	1,187
Taxes, other than income taxes	699	643	2,016	1,830
TOTAL OPERATING EXPENSES	2,364	2,150	6,948	6,218
OPERATING INCOME	728	722	1,836	1,854
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	5	6	15	11
Allowance for equity funds used during construction	5	1	14	10
Other deductions	(33)	(45)	(99)	(159)
TOTAL OTHER INCOME (DEDUCTIONS)	(23)	(38)	(70)	(138)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	705	684	1,766	1,716
INTEREST EXPENSE
Interest on long-term debt	194	179	564	537
Other interest	3	7	11	26
Allowance for borrowed funds used during construction	0	(4)	(8)	(9)
NET INTEREST EXPENSE	197	182	567	554
INCOME BEFORE INCOME TAX EXPENSE	508	502	1,199	1,162
INCOME TAX EXPENSE	90	97	188	199
NET INCOME	418	405	1,011	963
Electric
OPERATING REVENUES
Total operating revenues	2,952	2,770	7,180	6,660
Electric | Subsidiaries
OPERATING REVENUES
Total operating revenues	2,730	2,562	6,661	6,178
Gas
OPERATING REVENUES
Total operating revenues	341	289	1,907	1,673
OPERATING EXPENSES
Operating costs	83	55	461	364
Gas | Subsidiaries
OPERATING REVENUES
Total operating revenues	307	259	1,730	1,509
OPERATING EXPENSES
Operating costs	61	38	357	298
Steam
OPERATING REVENUES
Total operating revenues	55	51	393	385
Steam | Subsidiaries
OPERATING REVENUES
Total operating revenues	55	51	393	385
Non-utility
OPERATING REVENUES
Total operating revenues	265	223	781	568
Purchased power
OPERATING EXPENSES
Operating costs	548	503	1,448	1,192
Purchased power | Subsidiaries
OPERATING EXPENSES
Operating costs	481	447	1,294	1,065
Fuel
OPERATING EXPENSES
Operating costs	44	24	166	124
Fuel | Subsidiaries
OPERATING EXPENSES
Operating costs	44	24	166	124
Other operations and maintenance
OPERATING EXPENSES
Operating costs	849	736	2,443	2,116
Other operations and maintenance | Subsidiaries
OPERATING EXPENSES
Operating costs	650	597	1,848	1,714
CECONY
INTEREST EXPENSE
NET INCOME		405
CECONY | Subsidiaries
OPERATING EXPENSES
Depreciation and amortization	429	401	1,267	1,187
OPERATING INCOME	728	722	$ 1,836	$ 1,854
INTEREST EXPENSE
INCOME TAX EXPENSE	$ 90	$ 97

XML

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
NET INCOME	$ 469	$ 502	$ 1,007	$ 1,095
NET INCOME	538	493	1,122	1,058
LOSS/(INCOME) ATTRIBUTABLE TO NON-CONTROLLING INTEREST	69	(9)	115	(37)
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	2	2	8	7
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	2	2	8	7
COMPREHENSIVE INCOME	540	495	1,130	1,065
Subsidiaries
NET INCOME	418	405	1,011	963
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	0	0	0	2
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	0	0	0	2
COMPREHENSIVE INCOME	$ 418	405	$ 1,011	$ 965
CECONY
NET INCOME		405
OTHER COMPREHENSIVE INCOME, NET OF TAXES
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES		$ 0

XML

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Net income	$ 1,007	$ 1,095
Net income	1,122	1,058
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,511	1,428
Investment loss/impairment	211	0
Deferred income taxes	167	184
Rate case amortization and accruals	(14)	(30)
Common equity component of allowance for funds used during construction	(15)	(12)
Net derivative losses/(gains)	(26)	80
Unbilled revenue and net unbilled revenue deferrals	(72)	29
Other non-cash items, net	108	43
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(387)	(322)
Allowance for uncollectible accounts – customers	165	48
Materials and supplies, including fuel oil and gas in storage	(50)	(1)
Revenue decoupling mechanism receivable	(56)	(52)
Other receivables and other current assets	81	(32)
Taxes receivable	18	(6)
Prepayments	(576)	(517)
Accounts payable	(15)	19
Pensions and retiree benefits obligations	237	181
Pensions and retiree benefits contributions	(467)	(474)
Accrued taxes	(27)	13
Accrued interest	126	102
Superfund and environmental remediation costs	(12)	(8)
Distributions from equity investments	18	29
System benefit charge	3	(56)
Deferred charges, noncurrent assets and other regulatory assets	(705)	(443)
Deferred credits and other regulatory liabilities	578	35
Other current and noncurrent liabilities	(96)	35
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,712	1,368
INVESTING ACTIVITIES
Utility construction expenditures	(2,697)	(2,346)
Cost of removal less salvage	(242)	(216)
Non-utility construction expenditures	(289)	(414)
Proceeds from sale of assets	614	0
Divestiture of renewable electric projects, net	183	0
Other investing activities	10	16
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,437)	(2,984)
FINANCING ACTIVITIES
Net issuance of short-term debt	(834)	137
Issuance of long-term debt	1,979	1,675
Retirement of long-term debt	(1,904)	(463)
Debt issuance costs	(30)	(25)
Common stock dividends	(768)	(731)
Issuance of common shares - public offering	775	88
Issuance of common shares for stock plans	45	43
Distribution to noncontrolling interest	(15)	(11)
Sale of equity interest	256	0
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	(496)	713
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(1,221)	(903)
BALANCE AT BEGINNING OF PERIOD	1,436	1,217
BALANCE AT END OF PERIOD	215	314
Cash paid/(received) during the period for:
Interest	565	583
Income taxes	(9)	31
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	388	432
Issuance of common shares for dividend reinvestment	37	36
Electric and Gas Transmission Projects
INVESTING ACTIVITIES
Investments in electric and gas transmission projects	(16)	0
Renewable Electric Production Projects
INVESTING ACTIVITIES
Investments in electric and gas transmission projects	0	(24)
Subsidiaries
Net income	1,011	963
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,267	1,187
Deferred income taxes	166	201
Rate case amortization and accruals	(13)	(30)
Common equity component of allowance for funds used during construction	(14)	(10)
Unbilled revenue and net unbilled revenue deferrals	2	0
Other non-cash items, net	46	(9)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	(383)	(289)
Allowance for uncollectible accounts – customers	162	45
Materials and supplies, including fuel oil and gas in storage	(47)	6
Revenue decoupling mechanism receivable	(64)	(45)
Other receivables and other current assets	35	3
Accounts receivable from affiliated companies	18	(83)
Prepayments	(573)	(481)
Accounts payable	(49)	29
Accounts payable to affiliated companies	1	1
Pensions and retiree benefits obligations	234	169
Pensions and retiree benefits contributions	(430)	(434)
Accrued taxes	(31)	10
Accrued taxes to affiliated companies	6	3
Accrued interest	103	97
Superfund and environmental remediation costs	(19)	(14)
System benefit charge	3	(53)
Deferred charges, noncurrent assets and other regulatory assets	(666)	(420)
Deferred credits and other regulatory liabilities	509	112
Other current and noncurrent liabilities	(23)	1
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,251	959
INVESTING ACTIVITIES
Utility construction expenditures	(2,545)	(2,200)
Cost of removal less salvage	(237)	(212)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,782)	(2,412)
FINANCING ACTIVITIES
Net issuance of short-term debt	(718)	(146)
Issuance of long-term debt	1,500	1,600
Retirement of long-term debt	(640)	(350)
Debt issuance costs	(20)	(24)
Capital contribution by parent	1,101	200
Dividend to parent	(741)	(737)
NET CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES	482	543
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(1,049)	(910)
BALANCE AT BEGINNING OF PERIOD	1,067	933
BALANCE AT END OF PERIOD	18	23
Cash paid/(received) during the period for:
Interest	446	430
Income taxes	(2)	78
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	335	340
CECONY | Subsidiaries
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,267	1,187
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	24	51
Software Licenses | Subsidiaries
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	22	48
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	22	28
Equipment | Subsidiaries
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 22	$ 28

XML

CONSOLIDATED BALANCE SHEET (UNAUDITED) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
CURRENT ASSETS
Cash and temporary cash investments	$ 66	$ 1,272
Accounts receivable – customers, less allowance for uncollectible accounts of $313 and $148 in 2021 and 2020, respectively	1,923	1,701
Other receivables, less allowance for uncollectible accounts of $7 in 2021 and 2020	272	278
Taxes receivable	8	26
Accrued unbilled revenue	656	599
Fuel oil, gas in storage, materials and supplies, at average cost	405	356
Prepayments	847	271
Regulatory assets	205	266
Restricted cash	149	164
Revenue decoupling mechanism receivable	193	137
Other current assets	372	231
TOTAL CURRENT ASSETS	5,096	5,301
INVESTMENTS	1,078	1,816
UTILITY PLANT, AT ORIGINAL COST
General	4,091	3,880
TOTAL	53,179	50,738
Less: Accumulated depreciation	11,907	11,188
Net	41,272	39,550
Construction work in progress	2,264	2,474
NET UTILITY PLANT	43,536	42,024
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $590 and $522 in 2021 and 2020, respectively	4,202	3,893
Construction work in progress	209	638
NET PLANT	47,947	46,555
OTHER NONCURRENT ASSETS
Goodwill	446	446
Intangible assets, less accumulated amortization of $273 and $228 in 2021 and 2020, respectively	1,317	1,460
Regulatory assets	5,903	6,195
Operating lease right-of-use asset	817	837
Other deferred charges and noncurrent assets	334	285
TOTAL OTHER NONCURRENT ASSETS	8,817	9,223
TOTAL ASSETS	62,938	62,895
CURRENT LIABILITIES
Long-term debt due within one year	439	1,967
Term loan	0	165
Notes payable	1,036	1,705
Accounts payable	1,370	1,475
Customer deposits	286	311
Accrued taxes	123	150
Accrued interest	273	149
Accrued wages	113	108
Fair value of derivative liabilities	163	238
Regulatory liabilities	490	36
System benefit charge	460	528
Operating lease liabilities	113	96
Other current liabilities	389	426
TOTAL CURRENT LIABILITIES	5,255	7,354
NONCURRENT LIABILITIES
Provision for injuries and damages	177	178
Pensions and retiree benefits	1,424	2,257
Superfund and other environmental costs	841	857
Asset retirement obligations	602	576
Fair value of derivative liabilities	166	240
Deferred income taxes and unamortized investment tax credits	6,835	6,475
Operating lease liabilities	756	764
Regulatory liabilities	4,379	4,513
Other deferred credits and noncurrent liabilities	285	234
TOTAL NONCURRENT LIABILITIES	15,465	16,094
LONG-TERM DEBT	21,841	20,382
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	20,037	18,847
Noncontrolling interest	340	218
TOTAL EQUITY (See Statement of Equity)	20,377	19,065
TOTAL LIABILITIES AND EQUITY	62,938	62,895
Subsidiaries
CURRENT ASSETS
Cash and temporary cash investments	18	1,067
Accounts receivable – customers, less allowance for uncollectible accounts of $313 and $148 in 2021 and 2020, respectively	1,816	1,595
Other receivables, less allowance for uncollectible accounts of $7 in 2021 and 2020	141	134
Taxes receivable	5	8
Accrued unbilled revenue	506	523
Accounts receivable from affiliated companies	116	134
Fuel oil, gas in storage, materials and supplies, at average cost	338	291
Prepayments	732	159
Regulatory assets	187	244
Revenue decoupling mechanism receivable	193	129
Other current assets	297	123
TOTAL CURRENT ASSETS	4,349	4,407
INVESTMENTS	597	541
UTILITY PLANT, AT ORIGINAL COST
General	3,777	3,585
TOTAL	49,821	47,529
Less: Accumulated depreciation	10,961	10,297
Net	38,860	37,232
Construction work in progress	2,123	2,320
NET UTILITY PLANT	40,983	39,552
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $590 and $522 in 2021 and 2020, respectively	2	2
NET PLANT	40,985	39,554
OTHER NONCURRENT ASSETS
Regulatory assets	5,473	5,745
Operating lease right-of-use asset	552	578
Other deferred charges and noncurrent assets	222	142
TOTAL OTHER NONCURRENT ASSETS	6,247	6,465
TOTAL ASSETS	52,178	50,967
CURRENT LIABILITIES
Long-term debt due within one year	0	640
Notes payable	942	1,660
Accounts payable	1,101	1,232
Accounts payable to affiliated companies	23	22
Customer deposits	272	296
Accrued taxes	101	132
Accrued taxes to affiliated companies	7	1
Accrued interest	229	126
Accrued wages	103	97
Fair value of derivative liabilities	114	163
Regulatory liabilities	428	11
System benefit charge	407	475
Operating lease liabilities	85	73
Other current liabilities	315	319
TOTAL CURRENT LIABILITIES	4,127	5,247
NONCURRENT LIABILITIES
Provision for injuries and damages	171	172
Pensions and retiree benefits	1,179	1,943
Superfund and other environmental costs	765	780
Asset retirement obligations	529	508
Fair value of derivative liabilities	97	105
Deferred income taxes and unamortized investment tax credits	6,770	6,411
Operating lease liabilities	507	512
Regulatory liabilities	3,941	4,094
Other deferred credits and noncurrent liabilities	235	197
TOTAL NONCURRENT LIABILITIES	14,194	14,722
LONG-TERM DEBT	17,637	16,149
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	16,220	14,849
TOTAL LIABILITIES AND EQUITY	52,178	50,967
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	34,446	33,315
Electric | Subsidiaries
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	32,367	31,327
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	11,869	10,847
Gas | Subsidiaries
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	10,904	9,921
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,773	2,696
Steam | Subsidiaries
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,773	2,696
CECONY | Subsidiaries
CURRENT ASSETS
Regulatory assets	187	244
OTHER NONCURRENT ASSETS
Regulatory assets	5,473	5,745
CURRENT LIABILITIES
Regulatory liabilities	428	11
Operating lease liabilities	85
NONCURRENT LIABILITIES
Operating lease liabilities	507
Regulatory liabilities	$ 3,941	$ 4,094

XML

CONSOLIDATED BALANCE SHEET (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Accounts receivable - customers, allowance for uncollectible accounts	$ 313	$ 148
Other receivables, allowance for uncollectible accounts	7	7
Non-utility property, accumulated depreciation	590	522
Intangible assets, accumulated amortization	273	228
Subsidiaries
Accounts receivable - customers, allowance for uncollectible accounts	300	138
Other receivables, allowance for uncollectible accounts	5	4
Non-utility property, accumulated depreciation	$ 25	$ 25

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CONSOLIDATED STATEMENT OF EQUITY (UNAUDITED) - USD ($) shares in Millions, $ in Millions	Total	Subsidiaries	Common Stock	Common Stock Subsidiaries	Additional Paid-In Capital	Additional Paid-In Capital Subsidiaries	Retained Earnings	Retained Earnings Subsidiaries	Treasury Stock	Repurchased Con Edison Stock Subsidiaries	Capital Stock Expense	Capital Stock Expense Subsidiaries	Accumulated Other Comprehensive Income/(Loss)	Accumulated Other Comprehensive Income/(Loss) Subsidiaries	Non- controlling Interest	CECONY	CECONY Common Stock	CECONY Additional Paid-In Capital	CECONY Retained Earnings	CECONY Repurchased Con Edison Stock	CECONY Capital Stock Expense	CECONY Accumulated Other Comprehensive Income/(Loss)
Beginning Balance (shares) at Dec. 31, 2019			333	235					23
Beginning Balance at Dec. 31, 2019	$ 18,213		$ 35		$ 8,054		$ 11,100		$ (1,038)		$ (110)		$ (19)		$ 191
Beginning Balance at Dec. 31, 2019		$ 14,147		$ 589		$ 5,669		$ 8,919		$ (962)		$ (62)		$ (6)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	392						375								17
Net income		406						406
Common stock dividends	(255)	(246)					(255)	(246)
Issuance of common shares – public offering (shares)			1
Issuance of common shares - public offering	88				88
Issuance of common shares for stock plans	26				26
Capital contribution by parent		25				25
Other comprehensive income	5	1											5	1
Distributions to noncontrolling interest	(2)														(2)
Ending Balance (shares) at Mar. 31, 2020			334	235					23
Ending Balance at Mar. 31, 2020	18,467		$ 35		8,168		11,220		$ (1,038)		(110)		(14)		206
Ending Balance at Mar. 31, 2020		14,333		$ 589		5,694		9,079		(962)		(62)		(5)
Beginning Balance (shares) at Dec. 31, 2019			333	235					23
Beginning Balance at Dec. 31, 2019	18,213		$ 35		8,054		11,100		$ (1,038)		(110)		(19)		191
Beginning Balance at Dec. 31, 2019		14,147		$ 589		5,669		8,919		(962)		(62)		(6)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,095
Net income	1,058	963
Other comprehensive income	7
Ending Balance (shares) at Sep. 30, 2020			334						23								235
Ending Balance at Sep. 30, 2020	18,711		$ 35		8,228		11,391		$ (1,038)		(110)				217
Ending Balance at Sep. 30, 2020														(4)		$ 14,575	$ 589	$ 5,869	$ 9,145	$ (962)	$ (62)	$ (4)
Beginning Balance (shares) at Mar. 31, 2020			334	235					23
Beginning Balance at Mar. 31, 2020	18,467		$ 35		8,168		11,220		$ (1,038)		(110)		(14)		206
Beginning Balance at Mar. 31, 2020		14,333		$ 589		5,694		9,079		(962)		(62)		(5)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	202						190								12
Net income		152						152
Common stock dividends	(256)	(246)					(256)	(246)
Issuance of common shares for stock plans	30				30
Capital contribution by parent		25				25
Other comprehensive income		1												1
Distributions to noncontrolling interest	(2)														(2)
Ending Balance (shares) at Jun. 30, 2020			334	235					23
Ending Balance at Jun. 30, 2020	18,441		$ 35		8,198		11,154		$ (1,038)		(110)				216
Ending Balance at Jun. 30, 2020		14,265		$ 589		5,719		8,985		(962)		(62)		(4)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	502						493								9
Net income	493	405														405			405
Common stock dividends	(256)						(256)									(245)			(245)
Issuance of common shares - public offering	0
Issuance of common shares for stock plans	30				30
Capital contribution by parent																150		150
Other comprehensive income	2															0						0
Distributions to noncontrolling interest	(8)														(8)
Ending Balance (shares) at Sep. 30, 2020			334						23								235
Ending Balance at Sep. 30, 2020	18,711		$ 35		8,228		11,391		$ (1,038)		(110)				217
Ending Balance at Sep. 30, 2020														(4)		$ 14,575	$ 589	$ 5,869	$ 9,145	$ (962)	$ (62)	$ (4)
Beginning Balance (shares) at Dec. 31, 2020			342	235					23
Beginning Balance at Dec. 31, 2020	19,065		$ 36		8,808		11,178		$ (1,038)		(112)		(25)		218
Beginning Balance at Dec. 31, 2020	18,847	14,849		$ 589		6,169		9,122		(962)		(62)		(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	420						419								1
Net income		465						465
Common stock dividends	(265)	(247)					(265)	(247)
Issuance of common shares for stock plans	28				28
Capital contribution by parent		125				125
Other comprehensive income	4												4
Distributions to noncontrolling interest	(3)														(3)
Net proceeds from sale of equity interest	33														33
Ending Balance (shares) at Mar. 31, 2021			342	235					23
Ending Balance at Mar. 31, 2021	19,282		$ 36		8,836		11,332		$ (1,038)		(112)		(21)		249
Ending Balance at Mar. 31, 2021		15,192		$ 589		6,294		9,340		(962)		(62)		(7)
Beginning Balance (shares) at Dec. 31, 2020			342	235					23
Beginning Balance at Dec. 31, 2020	19,065		$ 36		8,808		11,178		$ (1,038)		(112)		(25)		218
Beginning Balance at Dec. 31, 2020	18,847	14,849		$ 589		6,169		9,122		(962)		(62)		(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,007
Net income	1,122	1,011
Other comprehensive income	8
Ending Balance (shares) at Sep. 30, 2021			354	235					23
Ending Balance at Sep. 30, 2021	20,377		$ 37		9,683		11,495		$ (1,038)		(123)		(17)		340
Ending Balance at Sep. 30, 2021	20,037	16,220		$ 589		7,270		9,392		(962)		(62)		(7)
Beginning Balance (shares) at Mar. 31, 2021			342	235					23
Beginning Balance at Mar. 31, 2021	19,282		$ 36		8,836		11,332		$ (1,038)		(112)		(21)		249
Beginning Balance at Mar. 31, 2021		15,192		$ 589		6,294		9,340		(962)		(62)		(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	118						165								(47)
Net income		128						128
Common stock dividends	(266)	(247)					(266)	(247)
Issuance of common shares – public offering (shares)			11
Issuance of common shares - public offering	775		$ 1		785						(11)
Issuance of common shares for stock plans	34				34
Capital contribution by parent		851				851
Other comprehensive income	2												2
Distributions to noncontrolling interest	(4)														(4)
Net proceeds from sale of equity interest	112														112
Ending Balance (shares) at Jun. 30, 2021			353	235					23
Ending Balance at Jun. 30, 2021	20,053		$ 37		9,655		11,231		$ (1,038)		(123)		(19)		310
Ending Balance at Jun. 30, 2021		15,924		$ 589		7,145		9,221		(962)		(62)		(7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	469						538								(69)
Net income	538	418						418
Common stock dividends	(274)	(247)					(274)	(247)
Issuance of common shares – public offering (shares)			1
Issuance of common shares - public offering	0
Issuance of common shares for stock plans	28				28
Capital contribution by parent		125				125
Other comprehensive income	2												2
Distributions to noncontrolling interest	(8)														(8)
Net proceeds from sale of equity interest	107														107
Ending Balance (shares) at Sep. 30, 2021			354	235					23
Ending Balance at Sep. 30, 2021	20,377		$ 37		$ 9,683		$ 11,495		$ (1,038)		$ (123)		$ (17)		$ 340
Ending Balance at Sep. 30, 2021	$ 20,037	$ 16,220		$ 589		$ 7,270		$ 9,392		$ (962)		$ (62)		$ (7)

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CONSOLIDATED STATEMENT OF EQUITY (UNAUDITED) (Parenthetical) - $ / shares	3 Months Ended
	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020
Statement of Stockholders' Equity [Abstract]
Common stock dividends per share (dollars per share)	$ 0.775	$ 0.775	$ 0.775	$ 0.76	$ 0.76	$ 0.76

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General

9 Months Ended

Sep. 30, 2021

Accounting Policies [Abstract]

General

General

These combined notes accompany and form an integral part of the separate interim 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 statement 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, 2020 and their separate unaudited financial statements (including the combined notes thereto) included in Part 1, Item 1 of their combined Quarterly Reports on Form 10-Q for the quarterly periods ended March 31, 2021 and June 30, 2021.

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., through its subsidiaries, develops, owns and operates renewable and sustainable energy infrastructure projects and provides energy-related products and services to wholesale and retail customers. Con Edison Transmission, Inc. invests in and seeks to develop electric transmission projects through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and manages, through joint ventures, investments in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See “Investments” in Note A and Note R.

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Summary of Significant Accounting Policies and Other Matters

9 Months Ended

Sep. 30, 2021

Accounting Policies [Abstract]

Summary of Significant Accounting Policies and Other Matters

Summary of Significant Accounting Policies and Other Matters

Accounting Policies

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

Investments

Con Edison's investments consist primarily of the investments of Con Edison Transmission that are accounted for under the equity method and the fair value of the Utilities' supplemental retirement income plan and deferred income plan assets.

Partial Impairment of Investment in Stagecoach Gas Services LLC (Stagecoach)

In May 2021, a subsidiary of Con Edison Gas Pipeline and Storage, LLC (CET Gas) entered into a purchase and sale agreement pursuant to which the subsidiary and its joint venture partner agreed to sell their combined interests in Stagecoach Gas Services LLC (Stagecoach) for a total of $1,225 million, of which $612.5 million will be CET Gas' portion for its 50 percent interest, subject to closing adjustments. The purchase and sale agreement contemplates a two-stage closing, the first of which was completed in July 2021 for a sale price of $1,195 million, of which $614 million, including working capital, was attributed to CET Gas. The second closing for the remaining $30 million, of which $15 million will be attributed to CET Gas, subject to closing adjustments, is to occur following approval by the New York State Public Service Commission, which is expected later this year or during the first quarter of 2022, subject to customary closing conditions.

As a result of information made available to Stagecoach as part of the sale process, Stagecoach performed impairment tests that resulted in Stagecoach recording impairment charges of $414 million for the nine months ended September 30, 2021. Accordingly, Con Edison recorded pre-tax impairment losses on its 50 percent interest

in Stagecoach of $211 million ($147 million after-tax), including working capital and transaction cost adjustments, within "Investment income/(loss)" on Con Edison's consolidated income statement for the nine months ended September 30, 2021. These charges reduced the carrying value of Con Edison’s investment in Stagecoach to $630 million at June 30, 2021.

Stagecoach’s impairment charges and information obtained from the sales process constituted triggering events for Con Edison's investment in Stagecoach as of March 31, 2021 and June 30, 2021. Con Edison evaluated the carrying value of its investment in Stagecoach for other-than-temporary declines in value using income and market-based approaches. Con Edison determined that the carrying value of its investment in Stagecoach of $667 million and $630 million as of March 31, 2021 and June 30, 2021, respectively, was not impaired. The carrying value of $630 million at June 30, 2021 approximates the final sales price received in July 2021 and the remaining amount expected to be received, including closing adjustments.

The accounting rules require Con Edison to evaluate its investments periodically to determine whether they are impaired. The standard for determining whether an impairment exists and must be recorded is whether an other-than-temporary decline in carrying value has occurred. Changes in economic conditions, forecasted cash flows and the regulatory environment, among other factors, could require equity method investments to recognize a decrease in carrying value for an other-than-temporary decline. When management believes such a decline may have occurred, the fair value of the investment is estimated using market inputs, when observable, or a market valuation model such as a discounted cash flow analysis. The fair value is compared to the carrying value of the investment in order to determine the amount of impairment to record, if any.

The evaluation and measurement of impairments involve uncertainties. The judgments that Con Edison makes to estimate the fair value of its equity method investments are based on assumptions that management believes are reasonable, and variations in these estimates or the underlying assumptions, or the receipt of additional market information, could have a material impact on whether a triggering event is determined to exist or the amount of any such impairment. Additionally, if the projects in which Con Edison holds these investments recognize an impairment, Con Edison may record a share of that impairment loss and would evaluate its investment for an other-than-temporary decline in carrying value as described above.

Reclassification

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

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 is 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 and nine months ended September 30, 2021 and 2020, basic and diluted EPS for Con Edison were calculated as follows:

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2021	2020	2021	2020
Net income for common stock	$538	$493	$1,122	$1,058
Weighted average common shares outstanding – basic	353.4	334.5	346.8	334.1
Add: Incremental shares attributable to effect of potentially dilutive securities	0.7	0.9	0.7	0.9
Adjusted weighted average common shares outstanding – diluted	354.1	335.4	347.5	335.0
Net Income per common share – basic	$1.52	$1.47	$3.23	$3.17
Net Income per common share – diluted	$1.52	$1.47	$3.23	$3.16

The computation of diluted EPS for the three and nine months ended September 30, 2021 and 2020 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 and nine months ended September 30, 2021 and 2020, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance, accumulated OCI, net of taxes (a)	$(19)	$(14)	$(7)	$(4)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2021 and 2020 (a)(b)	2	2	—	—
Current period OCI, net of taxes	2	2	—	—
Ending balance, accumulated OCI, net of taxes (a)	$(17)	$(12)	$(7)	$(4)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance, accumulated OCI, net of taxes (a)	$(25)	$(19)	$(7)	$(6)
OCI before reclassifications, net of tax of $(1) for Con Edison in 2021 and 2020	2	4	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2021 and 2020 (a)(b)	6	3	—	2
Current period OCI, net of taxes	8	7	—	2
Ending balance, accumulated OCI, net of taxes (a)	$(17)	$(12)	$(7)	$(4)

(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 and liabilities 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 costs. 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 September 30, 2021 and 2020, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows:

	At September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Cash and temporary cash investments	$66	$153	$18	$23
Restricted cash (a)	149	161	—	—
Total cash, temporary cash investments and restricted cash	$215	$314	$18	$23

(a)Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($149 million and $161 million at September 30, 2021 and 2020, respectively) that, under the related project debt agreements, is restricted to being used for normal operating expenses and capital expenditures, debt service, and required reserves until the various maturity dates of the project debt.

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Regulatory Matters

9 Months Ended

Sep. 30, 2021

Regulated Operations [Abstract]

Regulatory Matters

Regulatory Matters

Rate Plans

In October 2021, O&R, the New York State Department of Public Service (NYSDPS) and other parties entered into a Joint Proposal for new electric and gas rate plans for the three-year period January 2022 through December 2024 (the Joint Proposal). The Joint Proposal is subject to NYSPSC approval. The Joint Proposal includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over 3 years ($2.8 million); reconciliation of late payment charges to amounts reflected in rates for years 2021 through 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity; and reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates from January 1, 2020 through December 31, 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity. The following tables contain a summary of the proposed rate plans.

O&R New York – Electric
Effective period	January 2022 – December 2024 (c)
Base rate changes	Yr. 1 – $4.9 million (a) Yr. 2 – $16.2 million (a) Yr. 3 – $23.1 million (a)
Amortizations to income of net regulatory (assets) and liabilities (b)	Yr. 1 – $11.8 million Yr. 2 – $13.5 million Yr. 3 – $15.2 million
Other revenue sources	Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $3.3 million Yr. 2 – $2.3 million Yr. 3 – $4.0 million
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $4.3 million Yr. 2 – $4.4 million Yr. 3 – $5.1 million
Cost reconciliations	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (d), energy efficiency program (e), major storms, and certain other costs to amounts reflected in rates.
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target Yr. 1 – $1,175 million Yr. 2 – $1,198 million Yr. 3 – $1,304 million
Average rate base	Yr. 1 – $1,021 million Yr. 2 – $1,044 million Yr. 3 – $1,144 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent
Authorized return on common equity	9.2 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.7 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent
Common equity ratio	48 percent

(a) The Joint Proposal recommends that these base rate changes may be implemented with increases of: Yr. 1 - $11.7 million; Yr. 2 - $11.7 million; and Yr. 3 - $11.7 million.

(b) Reflects amortization of, among other things, previously incurred incremental deferred storm costs over a five-year period. See "Other Regulatory Matters," below.

(c) If at the end of any year, Con Edison’s investments in its non-utility businesses exceed 15 percent of Con Edison’s total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, O&R is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures are not necessary.

(d) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(e) Energy efficiency costs are expensed as incurred. Such costs are subject to a cumulative reconciliation that is evenly distributed over the term of the rate plan subject to the caps set forth in the January 2020 NYSPSC New Efficiency New York (“NENY”) order. If the NYSPSC modifies O&R's NENY budgets during the rate term, such modifications will be reflected at the time of the cumulative reconciliations.

O&R New York – Gas
Effective period	January 2022 – December 2024 (b)
Base rate changes	Yr. 1 – $0.7 million (a) Yr. 2 – $7.4 million (a) Yr. 3 – $9.9 million (a)
Amortization to income of net regulatory (assets) and liabilities	Yr. 1 – $0.8 million Yr. 2 – $0.7 million Yr. 3 – $0.3 million
Other revenue sources	Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $0.2 million Yr. 2 - $0.2 million Yr. 3 - $0.4 million Potential positive rate adjustment for gas safety and performance of up to: Yr. 1 – $1.2 million Yr. 2 – $1.3 million Yr. 3 – $1.4 million
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $6.3 million Yr. 2 – $6.7 million Yr. 3 – $7.3 million
Cost reconciliations	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (c), energy efficiency program (d), major storms and certain other costs to amounts reflected in rates.
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target Yr. 1 – $720 million Yr. 2 – $761 million Yr. 3 – $803 million
Average rate base	Yr. 1 – $566 million Yr. 2 – $607 million Yr. 3 – $649 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent
Authorized return on common equity	9.2 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.7 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt	Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent
Common equity ratio	48 percent

(a) The Joint Proposal recommends that these base rate changes may be implemented with increases of: Yr. 1 – $4.4 million; Yr. 2 - $4.4 million; and Yr. 3 - $4.4 million.

(b) If at the end of any year, Con Edison’s investments in its non-utility businesses exceed 15 percent of Con Edison’s total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, O&R is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures are not necessary.

(c) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(d) Energy efficiency costs are expensed as incurred. Such costs are subject to a cumulative reconciliation that is evenly distributed over the term of the rate plan subject to the caps set forth in the January 2020 NYSPSC New Efficiency New York (“NENY”) order. If the NYSPSC modifies O&R’s NENY budgets during the rate term, such modifications will be reflected at the time of the cumulative reconciliations.

Rockland Electric Company (RECO)

In May 2021, RECO filed a request with the New Jersey Board of Public Utilities (NJBPU) for an electric rate increase of $16.9 million, effective February 2022. The filing reflected a return on common equity of 10.00 percent and a common equity ratio of 49.25 percent. RECO also seeks an increase in its annual storm allowance of $1 million, recovery of deferred costs associated with Tropical Storm Isaias, and the collection of various deferred COVID-19 related costs. In October 2021, RECO filed an update to the request it filed in May 2021. The company increased its requested February 2022 rate increase to $19.5 million and decreased the common equity ratio to 48.84 percent. The updated filing continues to reflect a return on common equity of 10.00 percent.

In September 2021, RECO requested authorization from the NJBPU to defer $3.7 million in incremental storm preparation costs for Tropical Storm Henri.

COVID-19 Regulatory Matters

Governors, public utility commissions and other regulatory agencies in the states in which the Utilities operate have issued orders related to the COVID-19 pandemic that impact the Utilities as described below.

New York State Regulation

In March 2020, former New York State Governor Cuomo declared a State Disaster Emergency for the State of New York due to the COVID-19 pandemic and signed the "New York State on PAUSE" executive order that temporarily closed all non-essential businesses statewide. The former Governor then lifted these closures over time and ended the emergency declaration in June 2021. As a result of the emergency declaration, and due to economic conditions, the NYSPSC and the Utilities have worked to mitigate the potential impact of the COVID-19 pandemic on the Utilities, their customers and other stakeholders.

In March 2020, the Utilities began suspending service disconnections, certain collection notices, final bill collection agency activity, new late payment charges and certain other fees for all customers. The Utilities also began providing payment extensions for all customers that were scheduled to be disconnected prior to the start of the COVID-19 pandemic. In June 2020, the state of New York enacted a law prohibiting New York utilities, including CECONY and O&R, from disconnecting residential customers, and starting in May 2021 small business customers, during the COVID-19 state of emergency, which ended in June 2021. In addition, such prohibitions will apply for an additional 180 days after the state of emergency ends (December 21, 2021) for residential and small business customers who have experienced a change in financial circumstances due to the COVID-19 pandemic. For the three and nine months ended September 30, 2021, the estimated late payment charges and fees that were not billed were approximately $11 million and $46 million lower than the amounts that were approved to be collected pursuant to CECONY's rate plans, respectively, and $1 million and $3 million lower than the amounts that were approved to be collected pursuant to O&R's rate plans, respectively (see Note K). For the three and nine months ended September 30, 2020, the estimated late payment charges and fees that were not billed were approximately $17 million and $36 million lower than the amounts that were approved to be collected pursuant to CECONY's rate plans, respectively, and $1 million and $2 million lower than the amounts that were approved to be collected pursuant to O&R's rate plans, respectively (see Note K). In April 2021, CECONY filed a petition with the NYSPSC to timely establish a surcharge recovery mechanism to collect $52 million of late payment charges and fees, offset for related savings, for the year ended December 31, 2020 to begin in September 2021 and end in December 2022. The petition also requested a surcharge recovery or surcredit mechanism for any fee deferrals for 2021 and 2022 starting in January of the subsequent year over a twelve-month period, respectively. Public comments in response to the petition were filed in August 2021. CECONY resumed late payment charges for commercial and residential customers who have not experienced a change in financial circumstances due to the COVID-19 pandemic on September 3, 2021 and October 1, 2021, respectively. O&R resumed late payment charges for commercial and residential customers who have not experienced a change in financial circumstances due to the COVID-19 pandemic on October 1, 2021.

The Utilities’ New York rate plans allow them to defer costs resulting from a change in legislation, regulation and related actions that have taken effect during the term of the rate plans once the costs exceed a specified threshold. The total reserve increases to the allowance for uncollectible accounts from January 1, 2020 through September 30, 2021 reflecting the impact of the COVID-19 pandemic for CECONY electric and gas operations and O&R electric and gas operations were $235 million and $7 million, respectively, and were deferred pursuant to the legislative, regulatory and related actions provisions of the rate plans as a result of the New York State on PAUSE and related executive orders, that have since been lifted, as described above. The Utilities’ New York rate plans also provide for an allowance for write-offs of customer accounts receivable balances. The above amounts deferred pursuant to the legislative, regulatory and related actions provisions were reduced by the amount that the actual write-offs of customer accounts receivable balances were below the allowance reflected in rates which differences were $12 million and $2 million for CECONY and O&R, respectively, from March 1, 2020 through September 30, 2021.

In June 2020, the NYSPSC directed CECONY to implement a summer cooling credit program to help mitigate the cost of staying home and operating air conditioning for health-vulnerable low-income customers due to the limited availability of public cooling facilities as a result of the COVID-19 social distancing measures. The $63.4 million cost of the program is being recovered over a five-year period that began January 2021.

In June 2020, the NYSPSC established a generic proceeding on the impacts of the COVID-19 pandemic and sought comment on a variety of COVID-19 related issues. In July 2020, the Utilities submitted joint comments with other large utilities in New York State that included a formal request to defer all COVID-19 related costs and for a surcharge mechanism to collect such deferrals based upon the individual utility's need. In January 2021, the NYSDPS provided guidance to New York utilities that no additional mechanisms are required because there are already established mechanisms for utility recovery of unexpected material expenses through rate plan change in legislation, regulation and related actions provisions of their respective rate plans and the filing of individual deferral petitions. The guidance further provided that utilities deferring COVID-19 related costs pursuant to the provisions that allow deferral of costs resulting from a change in legislation, regulation and related actions must comply with the provisions of their rate plans, be able to demonstrate the nexus between the changes in law or regulation and the specific revenue and expense items, and consider any offsetting cost savings due to the pandemic.

As of December 31, 2020, CECONY deferred, for New York City residential customers, $54.9 million of higher summer generation capacity supply costs. CECONY recovered such costs from customers as of October 31, 2021.

In April 2021, New York State passed a law that creates a program that allows eligible residential renters in New York State who require assistance with rent and utility bills to have up to twelve months of electric and gas utility bill arrears forgiven, provided that such arrears were accrued on or after March 13, 2020. The program will be administered by the State Office of Temporary Disability Assistance in coordination with the NYSDPS. Under the program, CECONY and O&R would qualify for a refundable tax credit for New York State gross-receipts tax equal to the amount of arrears waived by the Utilities in the year that the arrears are waived and certified by the NYSPSC.

In May 2021, CECONY and O&R, along with other large New York utilities, submitted joint comments to the NYSDPS' February 2021 report on New York State’s Energy Affordability Policy. The report recommends, among other things, that residential and commercial customers’ late payment fees and interest on deferred payment agreements be waived until two years after the expiration of the New York State moratorium on utility terminations (the moratorium will expire on December 21, 2021) and each utility develop an arrears management program to mitigate the financial burdens of the COVID-19 pandemic on New York households and that program costs be shared, perhaps equally, between shareholders and customers. The May 2021 joint comments stated that it is not necessary for the NYSPSC to adopt the report’s COVID-19 related recommendations because New York State already passed laws that address the issues in the report, as described above.

The Utilities’ rate plans have revenue decoupling mechanisms in their New York electric and gas businesses that largely reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC per month and accumulate the deferred balances semi-annually under CECONY's electric rate plan (January through June and July through December, respectively) and annually under CECONY's gas rate plan and O&R's New York electric and gas rate plans (January through December). Differences are accrued with interest each month for CECONY's and O&R's New York electric customers and after the annual deferral period ends for CECONY's and O&R's New York gas customers for refund to, or recovery from customers, as applicable. Generally, the refund to or recovery from customers begins August and February of each year over an ensuing six-month period for CECONY's electric customers and February of each year over an ensuing twelve-month period for CECONY's gas and O&R's New York electric and gas customers.

New Jersey State Regulation

In March 2020, New Jersey Governor Murphy declared a Public Health Emergency and State of Emergency for the State of New Jersey. In June 2021, the Governor ended the emergency declaration. As a result of the emergency declaration, and due to economic conditions, the NJBPU and RECO have worked to mitigate the potential impact of the COVID-19 pandemic on RECO, its customers and other stakeholders. In March 2020, RECO began suspending late payment charges, terminations for non-payment, and no access fees during the COVID-19 pandemic. The suspension of these fees continued through July 31, 2021 and are not material.

In July 2020, the NJBPU authorized RECO and other New Jersey utilities to create a COVID-19-related regulatory asset by deferring prudently incurred incremental costs related to the COVID-19 pandemic beginning on March 9, 2020, and has extended such deferrals through December 31, 2022. RECO deferred net incremental COVID-19 related costs of $0.9 million through September 30, 2021.

Other Regulatory Matters

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, under its electric rate plan that was approved in January 2020, is amortizing its TCJA net benefits prior to January 1, 2019 allocable to its electric customers ($377 million) over a three-year period, the “protected” portion of its net regulatory liability for future income taxes related to certain accelerated tax depreciation benefits allocable to its electric customers ($1,663 million) over the remaining lives of the related assets and the remainder, or “unprotected” portion of the net regulatory liability allocable to its electric customers ($784 million) over a five-year period. CECONY, under its gas rate plan that was approved in January 2020, is amortizing its remaining TCJA net benefits prior to January 1, 2019 allocable to its gas customers ($63 million) over a two-year period, the protected portion of its net regulatory liability for future income taxes allocable to its gas customers ($725 million) over the remaining lives of the related assets and the unprotected portion of the net regulatory liability allocable to its gas customers ($107 million) over a five-year period.

CECONY's net benefits prior to October 1, 2018 allocable to the company’s steam customers ($15 million) are being 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 steam customers ($185 million) is being amortized over the remaining lives of the related assets (with the amortization period for the unprotected portion subject to review in its next steam rate proceeding).

O&R, under its current electric and gas rate plans, has reflected its TCJA net benefits in its electric and gas rates beginning as of January 1, 2019. Under the rate plans, O&R is amortizing its net benefits prior to January 1, 2019 ($22 million) over a three-year period, the protected portion of its net regulatory liability for future income taxes ($123 million) over the remaining lives of the related assets and the unprotected portion ($30 million) over a fifteen-year period. Pursuant to the October 2021 Joint Proposal, O&R will amortize the remaining unprotected portion of its net regulatory liability for future income taxes ($34 million) over a six-year period beginning January 1, 2022.

In January 2018, the NYSPSC issued an order initiating a focused operations audit of the Utilities’ financial accounting for income taxes. The audit is investigating the Utilities’ inadvertent understatement of a portion, the amount of which may be material, of their calculation of total federal income tax expense for ratemaking purposes. The understatement was related to the calculation of plant retirement-related cost of removal. As a result of such understatement, the Utilities accumulated significant income tax regulatory assets that were not reflected in O&R’s rate plans prior to 2014, CECONY’s electric and gas rate plans prior to 2015 and 2016, respectively, and is currently not reflected in CECONY’s steam rate plan. As part of the audit, the Utilities plan to pursue a private letter ruling from the Internal Revenue Service (IRS) that is expected to confirm, among other things, that in order to comply with IRS normalization rules, such understatement may not be corrected through a write-down of a portion of the regulatory asset and must be corrected through an increase in future years’ revenue requirements. The regulatory asset ($1,180 million and $26 million for CECONY and O&R, respectively, as of September 30, 2021 and $1,200 million and $29 million for CECONY and O&R, respectively, as of December 31, 2020) is netted against the future income tax regulatory liability on the Companies’ consolidated balance sheet. The Utilities are unable to estimate the amount or range of their possible loss, if any, related to this matter. At September 30, 2021, the Utilities have not accrued a liability related to this matter.

In October 2020, the NYSPSC issued an order instituting a proceeding to consider requiring New York’s large, investor-owned utilities, including CECONY and O&R, to annually disclose what risks climate change poses to their companies, investors and customers going forward. The order notes that some holding companies, including Con Edison, already disclose climate change risks at the holding company level, but states that the NYSPSC believes that climate-related risk disclosures should be issued specific to the operating companies in New York, such as CECONY and O&R, and that such climate-related risk disclosures should be included annually with the utilities’ financial reports. In December 2020, CECONY and O&R, along with other large New York utilities, filed comments supporting climate change risk disclosures in annual reports filed with the NYSPSC and recommended the use of an industry-specific template.

In May 2020, the president of the United States issued the "Securing the United States Bulk-Power System" executive order. The executive order declares threats to the bulk-power system by foreign adversaries constitute a national emergency and prohibits the acquisition, importation, transfer or installation of certain bulk-power system electric equipment that is sourced from foreign adversaries. In January 2021, the president of the United States suspended the May 2020 executive order for 90 days. In April 2021, the executive order was reinstated (and expired shortly thereafter) and the Department of Energy (DOE) subsequently issued a request for information to assist the DOE in developing additional orders and/or regulations to secure the United States’ critical electric infrastructure. In September 2021, the Cybersecurity and Infrastructure Security Agency and the National Institute of Standards and Technology issued preliminary cybersecurity goals for critical infrastructure control systems, with final goals to be issued by September 2022. The Companies are unable to predict the impact on them of any orders or regulations that may be adopted regarding critical infrastructure.

In July 2021, the NYSPSC approved a settlement agreement among CECONY, O&R and the NYSDPS that fully resolves all issues and allegations that have been raised or could have been raised by the NYSPSC against CECONY and O&R with respect to: (1) the July 2018 rupture of a CECONY steam main located on Fifth Avenue and 21st Street in Manhattan (the “2018 Steam Incident”); (2) the July 2019 electric service interruptions to approximately 72,000 CECONY customers on the west side of Manhattan and to approximately 30,000 CECONY customers primarily in the Flatbush area of Brooklyn (the “2019 Manhattan and Brooklyn Outages”); (3) the August 2020 electric service interruptions to approximately 330,000 CECONY customers and approximately 200,000 O&R customers following Tropical Storm Isaias (the “Tropical Storm Isaias Outages”) and (4) the August 2020 electric service interruptions to approximately 190,000 customers resulting from faults at CECONY’s Rainey substation following Tropical Storm Isaias (the “Rainey Outages”). Pursuant to the settlement agreement, CECONY and O&R agreed to a total settlement amount of $75.1 million and $7.0 million, respectively. CECONY and O&R agreed to forgo recovery from customers of $25 million and $2.5 million, respectively, associated with the return on existing storm hardening assets beginning with the next rate plan for each utility (over a period of 35 years). CECONY and O&R also agreed to incur ongoing operations and maintenance costs of up to $15.8 million and $2.9 million, respectively, for, among other things, costs to maintain a certain level of contractor and vehicle storm emergency support and storm preparation audits. For CECONY, the settlement agreement includes previously incurred or accrued costs of $34.3 million, including negative revenue adjustments of $5 million for the Rainey Outages and $15 million for the 2019 Manhattan and Brooklyn Outages and $14.3 million in costs to reimburse customers for food and medicine spoilage and other previously incurred expenses related to Tropical Storm Isaias and the 2018 Steam Incident. For O&R, the settlement agreement includes previously incurred costs of $1.6 million to reimburse customers for food and medicine spoilage and other expenses related to the Tropical Storm Isaias Outages.

Additional information relating to the 2018 Steam Incident, 2019 Manhattan and Brooklyn Outages and Tropical Storm Isaias Outages follow.

2018 Steam Incident: In July 2018, the NYSPSC commenced an investigation into the rupture of a CECONY steam main located on Fifth Avenue and 21st Street in Manhattan. 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. As of June 30, 2021, with respect to the incident, the company incurred operating costs of $17 million for property damage, clean-up and other response costs and invested $9 million in capital and retirement costs. During the second quarter of 2020, the company accrued a $3 million liability related to this matter. As described above, in July 2021, CECONY entered into a settlement agreement that fully resolves all issues and allegations with respect to this matter.

2019 Manhattan and Brooklyn Outages: In July 2019, electric service was interrupted to approximately 72,000 CECONY customers on the west side of Manhattan. Also in July 2019, electric service was interrupted to approximately 30,000 CECONY customers primarily in the Flatbush area of Brooklyn. In November 2020, the NYSPSC issued an order in its proceedings investigating these July 2019 power outages ordering CECONY to

show cause why the NYSPSC should not commence a review of the prudency of CECONY’s actions and/or omissions prior to, during, and after the July 2019 outages in Manhattan and Brooklyn, and pursue civil or administrative penalties in the amount of up to $24.8 million for CECONY’s alleged failure to comply with certain requirements. The order further indicated that should the NYSPSC confirm some or all of the apparent violations identified in the order or other orders issued by the NYSPSC in the future in connection with this proceeding, and should such confirmed violations be classified as findings of repeated violations of the Public Service Law or rules or regulations adopted pursuant thereto that demonstrate a failure of CECONY to continue to provide safe and adequate service, the NYSPSC would be authorized to commence a proceeding under Public Service Law Section 68(2) to revoke or modify CECONY’s certificate as it relates to its service territory or any portion thereof.

In December 2020, CECONY filed a response to the NYSPSC order demonstrating why the NYSPSC should not commence a penalty or prudence action against CECONY. CECONY stated that the NYSPSC order misapplied Section 25-a of the Public Service Law by ignoring the reasonable compliance standard under the statute and instead, was imposing a strict liability standard. For both outages, CECONY presented evidence that it either had complied or reasonably complied with NYSPSC requirements. With respect to the Manhattan outage, CECONY stated that a prudency proceeding was not justified because CECONY’s actions with respect to the Manhattan outage were reasonable based on the information the company had at the time. With respect to the Brooklyn outage, the company stated that the order failed to allege that improper company actions caused the outage. During 2019, CECONY recorded negative revenue adjustments associated with reliability performance provisions of $15 million in aggregate primarily related to these outages. As described above, in July 2021, CECONY entered into a settlement agreement that fully resolves all issues and allegations with respect to this matter.

Tropical Storm Isaias Outages: In August 2020, Tropical Storm Isaias caused significant damage to the Utilities’ electric distribution systems and interrupted service to approximately 330,000 CECONY electric customers and approximately 200,000 O&R electric customers. As of September 30, 2021, CECONY incurred costs for Tropical Storm Isaias of $175 million (including $84 million of operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan, $64 million of capital expenditures and $27 million (including $7.5 million for food and medicine spoilage claims) of operation and maintenance expenses). As of September 30, 2021, O&R incurred costs for Tropical Storm Isaias of $26.5 million (including $19.2 million of operation and maintenance expenses charged against a storm reserve pursuant to its New York electric rate plan, $5.7 million of capital expenditures and $1.6 million for food and medicine spoilage claims). As of September 30, 2021, RECO incurred costs for Tropical Storm Isaias of $11.3 million (including $7.5 million of operation and maintenance expenses charged against a storm reserve pursuant to its rate plan, $2.5 million of capital expenditures and $1.3 million for food and medicine spoilage claims). The Utilities’ electric rate plans provide for recovery of operating costs and capital expenditures under different provisions. The Utilities’ incremental operating costs attributable to storms are to be deferred for recovery as a regulatory asset under their electric rate plans, while capital expenditures, up to specified levels, are reflected in rates under their electric rate plans. The provisions of the Utilities’ New York electric rate plans that impose negative revenue adjustments for operating performance provide for exceptions for major storms and catastrophic events beyond the control of the companies, including natural disasters such as hurricanes and floods.

In November 2020, the NYSPSC issued an order in its proceedings investigating the New York utilities’ preparation for and response to Tropical Storm Isaias that ordered the Utilities to show cause why (i) civil penalties or appropriate injunctive relief should not be imposed against CECONY (in the amount of up to $102.3 million relating to 33 alleged violations) and against O&R (in the amount of up to $19 million relating to 38 alleged violations) to remedy such noncompliance, and (ii) a prudence proceeding should not be commenced against the Utilities for potentially imprudent expenditures of ratepayer funds related to the matter. The order stated that given the continuing nature of the investigation of this matter by the NYSDPS, the NYSPSC may amend the order to include any subsequently determined apparent violations identified by the NYSDPS. In addition, the order indicated that should the NYSPSC confirm some or all of the apparent violations identified in the order or other orders issued by the NYSPSC in the future in connection with this proceeding, and should such respective confirmed violations be classified as findings of repeated violations of the Public Service Law or rules or regulations adopted pursuant thereto that demonstrate a failure of CECONY and/or O&R to continue to provide safe and adequate service, the NYSPSC would be authorized to commence a proceeding under Public Service Law Section 68(2) to revoke or modify CECONY’s and/or O&R’s certificate as it relates to its service territory or any portion thereof.

In December 2020, CECONY and O&R filed responses to the NYSPSC order demonstrating why the NYSPSC should not commence penalty or prudence actions against them. The Utilities stated that the NYSPSC orders misapplied Section 25-a of the Public Service Law by ignoring the reasonable compliance standard under the statute and instead, was imposing a strict liability standard. CECONY and O&R also presented evidence that the order either misrepresented the applicable requirements or ignored that the Utilities were acting pursuant to

practices approved by the NYSPSC. Finally, CECONY and O&R stated that there was no basis to commence a prudence proceeding because the Utilities acted reasonably based on the information available and the circumstances at the time. As described above, in July 2021, CECONY and O&R entered into a settlement agreement that fully resolves all issues and allegations with respect to this matter.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at September 30, 2021 and December 31, 2020 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Regulatory assets
Unrecognized pension and other postretirement costs	$2,527	$3,241	$2,394	$3,065
Environmental remediation costs	846	865	780	791
Pension and other postretirement benefits deferrals	438	315	382	272
Revenue taxes	385	356	369	342
COVID-19 pandemic deferrals	274	115	269	113
Deferred storm costs	277	195	155	83
Property tax reconciliation	245	241	245	239
MTA power reliability deferral	152	188	152	188
System peak reduction and energy efficiency programs	145	124	145	124
Deferred derivative losses - long term	136	120	124	111
Municipal infrastructure support costs	49	62	49	62
Brooklyn Queens demand management program	35	36	35	36
Meadowlands heater odorization project	30	32	30	32
Preferred stock redemption	20	21	20	21
Non-wire alternative projects	23	18	23	18
Unamortized loss on reacquired debt	17	21	15	19
Recoverable REV demonstration project costs	15	20	14	18
Gate station upgrade project	15	25	15	25
Other	274	200	257	186
Regulatory assets – noncurrent	5,903	6,195	5,473	5,745
Deferred derivative losses - short term	166	190	155	177
Recoverable energy costs	39	76	32	67
Regulatory assets – current	205	266	187	244
Total Regulatory Assets	$6,108	$6,461	$5,660	$5,989
Regulatory liabilities
Future income tax	$2,040	$2,207	$1,896	$2,062
Allowance for cost of removal less salvage	1,114	1,090	950	932
Net unbilled revenue deferrals	184	198	184	198
TCJA net benefits*	167	295	164	286
Net proceeds from sale of property	111	137	111	137
Deferred derivative gains - long term	110	5	101	4
Pension and other postretirement benefit deferrals	98	85	53	46
System benefit charge carrying charge	71	64	63	57
Property tax refunds	35	36	35	35
BQDM and REV Demo reconciliations	26	27	22	25
Sales and use tax refunds	18	16	17	16
Energy efficiency portfolio standard unencumbered funds	17	1	19	—
Earnings sharing - electric, gas and steam	13	15	10	10
Unrecognized other postretirement costs	12	11	—	—
Settlement of gas proceedings	11	21	11	21
Settlement of prudence proceeding	6	5	6	5
Workers' compensation	5	3	5	3
Other	341	297	294	257
Regulatory liabilities – noncurrent	4,379	4,513	3,941	4,094
Deferred derivative gains - short term	451	8	423	7
Refundable energy costs	31	28	5	4
Revenue decoupling mechanism	8	—	—	—
Regulatory liabilities – current	490	36	428	11
Total Regulatory Liabilities	$4,869	$4,549	$4,369	$4,105

* See "Other Regulatory Matters," above.

The recognition of the return on regulatory assets is determined by the Utilities’ rate plans or orders issued by state regulators. In general, the Utilities receive or are being credited with a return at the Other Customer-Provided

Capital rate for regulatory assets that have not been included in rate base, and receive or are being credited with a return at the pre-tax weighted average cost of capital once the asset is included in rate base. Similarly, the Utilities pay to or credit customers with a return at the Other Customer-Provided Capital rate for regulatory liabilities that have not been included in rate base, and pay to or credit customers with a return at the pre-tax weighted average cost of capital once the liability is included in rate base. The Other Customer-Provided Capital rate for the nine months ended September 30, 2021 and 2020 was 1.80 percent and 2.65 percent, respectively.

In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made ($2,027 million and $1,696 million for Con Edison, and $1,817 million and $1,509 million for CECONY at September 30, 2021 and December 31, 2020, respectively). Regulatory assets of RECO for which a cash outflow has been made ($24 million and $31 million at September 30, 2021 and December 31, 2020, respectively) are not receiving or being credited with a return. RECO recovers regulatory assets over a period of up to four years or until they are addressed in its next base rate case in accordance with the rate provisions approved by the New Jersey Board of Public Utilities. Regulatory liabilities are treated in a consistent manner.

Regulatory assets that represent future financial obligations and were deferred in accordance with the Utilities’ rate plans or orders issued by state regulators do not earn a return until such time as a cash outlay has been made. Regulatory liabilities are treated in a consistent manner. At September 30, 2021 and December 31, 2020, regulatory assets for Con Edison and CECONY that did not earn a return consisted of the following items:

Regulatory Assets Not Earning a Return*

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Unrecognized pension and other postretirement costs	$2,527	$3,241	$2,394	$3,065
Environmental remediation costs	832	855	765	781
Revenue taxes	364	336	349	323
Deferred derivative losses - long term	136	120	124	111
Other	56	24	56	24
Deferred derivative losses - current	166	190	155	177
Total	$4,081	$4,766	$3,843	$4,481

*This table includes regulatory assets not earning a return for which no cash outlay has been made.

The recovery periods for regulatory assets for which a cash outflow has not been made and that do not earn a return have not yet been determined, except as noted below, and are expected to be determined pursuant to the Utilities’ future rate plans to be filed or orders issued by the state regulators in connection therewith.

The Utilities recover unrecognized pension and other postretirement costs over 10 years pursuant to NYSPSC policy.

The deferral for revenue taxes represents the New York State metropolitan transportation business tax surcharge on the cumulative temporary differences between the book and tax basis of assets and liabilities of the Utilities, as well as the difference between taxes collected and paid by the Utilities to fund mass transportation. The Utilities recover the majority of the revenue taxes over the remaining book lives of the electric and gas plant assets, as well as the steam plant assets for CECONY.

The Utilities recover deferred derivative losses – current within one year, and noncurrent generally within three years.

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Capitalization

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Capitalization

Capitalization

In February 2021, a subsidiary of the Clean Energy Businesses borrowed $250 million at a variable-rate, due 2028, secured by equity interests in four of the company’s solar electric production projects, the interest rate for which was swapped to a fixed rate of 3.39 percent.

In February 2021, a subsidiary of the Clean Energy Businesses entered into an agreement with a tax equity investor for the financing of a portfolio of three of the Clean Energy Businesses’ solar electric production projects (CED Nevada Virginia). Under the financing, the tax equity investor acquired a noncontrolling interest in the portfolio and will receive a percentage of earnings, tax attributes and cash flows. As of September 30, 2021, the tax equity investor fully funded its $263 million financing obligation. The Clean Energy Businesses will continue to consolidate this entity and will report the noncontrolling tax equity investor’s interest in the tax equity arrangement. See Note P.

In March 2021, a subsidiary of the Clean Energy Businesses agreed to issue $229 million aggregate principal amount of 3.77 percent senior notes, due 2046, secured by equity interests in CED Nevada Virginia, all of which had been issued at September 30, 2021.

During the first quarter of 2021, Con Edison optionally prepaid the remaining $675 million outstanding under a February 2019 term loan prior to its maturity in June 2021.

In May 2021, Con Edison redeemed at maturity $500 million of 2.00 percent 5-year debentures.

In June 2021, CECONY redeemed at maturity $640 million of floating rate 3-year debentures.

In June 2021, CECONY issued $750 million aggregate principal amount of 2.40 percent debentures, due 2031 and $750 million aggregate principal amount of 3.60 percent debentures, due 2061.

In June 2021, Con Edison issued 10,100,000 shares of its common stock resulting in net proceeds of approximately $775 million, after issuance expenses.

In June 2021, as part of the Clean Energy Businesses’ sale of a renewable electric production project, $104 million of 4.52 percent senior notes, due 2032 and $37 million of floating rate loans, due 2024 and loan-related interest rate swaps were assumed by the buyer pursuant to the sale agreement. See Notes N and R.

In September 2021, O&R agreed to issue in December 2021 $45 million aggregate principal amount of 2.31 percent debentures, due 2031 and $30 million aggregate principal amount of 3.17 percent debentures, due 2051.

The carrying amounts and fair values of long-term debt at September 30, 2021 and December 31, 2020 were:

(Millions of Dollars)	2021		2020
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$22,280	$25,655	$22,349	$26,808
CECONY	$17,637	$20,774	$16,789	$20,974

(a)Amounts shown are net of unamortized debt expense and unamortized debt discount of $221 million and $188 million for Con Edison and CECONY, respectively, as of September 30, 2021 and $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020.

The fair values of the Companies' long-term debt have been estimated primarily using available market information and at September 30, 2021 are classified as Level 2 liabilities (see Note O).

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Short-Term Borrowing

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Short-Term Borrowing

Short-Term BorrowingAt September 30, 2021, Con Edison had $1,036 million of commercial paper outstanding of which $942 million was outstanding under CECONY’s program. The weighted average interest rate at September 30, 2021 was 0.1 percent for both Con Edison and CECONY. At December 31, 2020, Con Edison had $1,705 million of commercial paper outstanding of which $1,660 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2020 was 0.3 percent for both Con Edison and CECONY.

At September 30, 2021 and December 31, 2020, 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 September 30, 2021 and December 31, 2020.

In August 2021, a subsidiary of the Clean Energy Businesses prepaid in full $249 million of borrowings outstanding under, and terminated, a $613 million variable-rate construction loan facility that was secured by and used to fund construction costs for CED Nevada Virginia. At December 31, 2020, the banks’ commitments under the construction loan facility were $613 million, and $165 million of borrowings were outstanding under the construction loan facility.

In April 2021, Con Edison entered into a credit agreement (April 2021 Credit Agreement) under which banks were committed until May 18, 2021, subject to certain conditions, to provide to Con Edison a $500 million variable-rate 364-day term loan. In May 2021, Con Edison borrowed $500 million under the April 2021 Credit Agreement to repay in full all of Con Edison’s outstanding 2.00 percent debentures, Series 2016 A, that matured on May 15, 2021. In July 2021, Con Edison prepaid in full the $500 million borrowing under the April 2021 Credit Agreement with a portion of the cash proceeds received from the substantial completion of the sale of Stagecoach. See Note R.

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Pension Benefits

9 Months Ended

Sep. 30, 2021

Retirement Benefits [Abstract]

Pension Benefits

Pension Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit cost for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost – including administrative expenses	$85	$73	$80	$69
Interest cost on projected benefit obligation	118	137	111	129
Expected return on plan assets	(274)	(258)	(260)	(245)
Recognition of net actuarial loss	197	175	187	165
Recognition of prior service credit	(4)	(4)	(5)	(5)
TOTAL PERIODIC BENEFIT COST	$122	$123	$113	$113
Cost capitalized	(41)	(34)	(39)	(32)
Reconciliation to rate level	(54)	(62)	(52)	(59)
Total expense recognized	$27	$27	$22	$22

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost – including administrative expenses	$257	$220	$241	$206
Interest cost on projected benefit obligation	353	412	332	387
Expected return on plan assets	(822)	(775)	(779)	(735)
Recognition of net actuarial loss	590	524	559	496
Recognition of prior service credit	(12)	(12)	(15)	(15)
TOTAL PERIODIC BENEFIT COST	$366	$369	$338	$339
Cost capitalized	(120)	(98)	(113)	(93)
Reconciliation to rate level	(165)	(188)	(158)	(179)
Total expense recognized	$81	$83	$67	$67

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 September 30, 2021, the Companies expect to make contributions to the pension plans during 2021 of $467 million (of which $429 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 nine months of 2021, the Companies contributed $465 million to the pension plans, $428 million of which was contributed by CECONY. CECONY also contributed $22 million to the external

trust for its non-qualified supplemental plan.

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Other Postretirement Benefits

9 Months Ended

Sep. 30, 2021

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 and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost - including administrative expenses	$2	$5	$1	$4
Interest cost on projected other postretirement benefit obligation	7	9	6	8
Expected return on plan assets	(17)	(16)	(14)	(14)
Recognition of net actuarial loss	4	3	3	3
Recognition of prior service credit	—	(1)	—	—
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(4)	$—	$(4)	$1
Cost capitalized	(3)	(2)	(3)	(2)
Reconciliation to rate level	7	2	6	—
Total credit recognized	$—	$—	$(1)	$(1)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost - including administrative expenses	$15	$16	$11	$12
Interest cost on projected other postretirement benefit obligation	23	28	19	23
Expected return on plan assets	(51)	(49)	(41)	(41)
Recognition of net actuarial loss	17	34	13	32
Recognition of prior service credit	(2)	(3)	(1)	(1)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$2	$26	$1	$25
Cost capitalized	(9)	(7)	(7)	(5)
Reconciliation to rate level	7	(19)	2	(24)
Total credit recognized	$—	$—	$(4)	$(4)

For information about the presentation of the components of other postretirement benefit costs, see Note E.

Contributions

During the first nine months of 2021, the Companies contributed $2 million (all of which was made by CECONY) to the other postretirement benefit plans. The Companies' policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

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Environmental Matters

9 Months Ended

Sep. 30, 2021

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 September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Accrued Liabilities:
Manufactured gas plant sites	$737	$752	$662	$676
Other Superfund Sites	104	105	103	104
Total	$841	$857	$765	$780
Regulatory assets	$846	$865	$780	$791

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 and nine months ended September 30, 2021 and 2020 were as follows: 

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Remediation costs incurred	$7	$8	$7	$8

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Remediation costs incurred	$21	$17	$20	$16

Insurance and other third-party recoveries received by Con Edison or CECONY were immaterial for the three and nine months ended September 30, 2021 and 2020.

In 2020, 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 $2.7 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 September 30, 2021, 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 or liabilities for the Companies at September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$68	$72	$65	$68
Regulatory liability – workers’ compensation	$5	$3	$5	$3

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Other Material Contingencies

9 Months Ended

Sep. 30, 2021

Commitments and Contingencies Disclosure [Abstract]

Other Material Contingencies

Other Material Contingencies

Manhattan Explosion and Fire

On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th 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 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. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At September 30, 2021 and December 31, 2020, the company had accrued its estimated liability for the suits of $40 million and an insurance receivable in the same amount.

Other Contingencies

For additional contingencies, see "Other Regulatory Matters" in Note B, Note G 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 and its subsidiaries under these agreements totaled $2,210 million and $2,042 million at September 30, 2021 and December 31, 2020, respectively.

A summary, by type and term, of amounts guaranteed by Con Edison and its subsidiaries under these agreements at September 30, 2021 is as follows:

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years	Total
	(Millions of Dollars)
Con Edison Transmission	$547	$—	$—	$547
Energy transactions	475	33	323	831
Renewable electric production projects	320	64	378	762
Other	70	—	—	70
Total	$1,412	$97	$701	$2,210

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 owns a 45.7 percent interest in NY Transco. In April 2019, the New York Independent System Operator (NYISO) selected a transmission project that was jointly proposed by National Grid and NY Transco. The siting, construction and operation of the project will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO indicated it will work with the developers to enter into agreements for the development and operation of the projects, including a schedule for entry into service by December 2023. Guarantee amount shown includes the maximum possible required amount of CET Electric’s contributions for this project as calculated based on the assumptions that the project is completed at 175 percent of its estimated costs and NY Transco does not use any debt financing for the project. Guarantee amount shown also includes a $7 million guarantee from Con Edison Transmission on behalf of a subsidiary of CET Gas related to the completion of the sale of Stagecoach. See "Investments" in Note A and Note R.

Energy Transactions — Con Edison and the Clean Energy Businesses guarantee payments on behalf of their subsidiaries 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 and the Clean Energy Businesses 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 the operation of solar energy facilities and energy service projects of the Clean Energy Businesses.

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Leases

9 Months Ended

Sep. 30, 2021

Leases [Abstract]

Leases

Leases

Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Operating lease cost	$22	$21	$16	$16
Operating lease cash flows	$10	$10	$6	$6

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Operating lease cost	$65	$63	$49	$48
Operating lease cash flows	$26	$27	$15	$13

As of September 30, 2021, assets recorded as finance leases were $2 million for Con Edison and $1 million for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $2 million, respectively. As of December 31, 2020, assets recorded as finance leases were $3 million for Con Edison and $2 million for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively.

For the three and nine months ended September 30, 2021 and 2020, finance lease costs and cash flows for Con Edison and CECONY were immaterial.

Right-of-use assets obtained in exchange for operating lease obligations for Con Edison and CECONY were $15 million and $5 million, respectively, for the three months ended September 30, 2021 and $32 million and $7 million, respectively for the nine months ended September 30, 2021. Right-of-use assets obtained in exchange for operating lease obligations for Con Edison and CECONY were $8 million and $2 million, respectively, for the three months ended September 30, 2020 and $13 million and $3 million, respectively for the nine months ended September 30, 2020.

Other information related to leases for Con Edison and CECONY at September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
	2021	2020	2021	2020
Weighted Average Remaining Lease Term:
Operating leases	18.5 years	19.1 years	12.4 years	13.0 years
Finance leases	7.1 years	7.3 years	3.3 years	4.0 years
Weighted Average Discount Rate:
Operating leases	4.3%	4.3%	3.6%	3.6%
Finance leases	1.8%	1.8%	1.2%	1.3%

Future minimum lease payments under non-cancellable leases at September 30, 2021 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending September 30,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2022	$82	$1	$59	$1
2023	76	—	58	—
2024	75	—	57	—
2025	76	—	58	—
2026	75	—	58	—
All years thereafter	937	1	446	—
Total future minimum lease payments	$1,321	$2	$736	$1
Less: imputed interest	(452)	—	(144)	—
Total	$869	$2	$592	$1
Reported as of September 30, 2021
Operating lease liabilities (current)	$113	$—	$85	$—
Operating lease liabilities (noncurrent)	756	—	507	—
Other current liabilities	—	1	—	—
Other noncurrent liabilities	—	1	—	1
Total	$869	$2	$592	$1

At September 30, 2021, the Companies did not have material obligations under operating or finance leases that had not yet commenced.

The Companies are lessors under certain leases whereby the Companies own real estate and distribution poles and lease portions of them to others. Revenue under such leases was immaterial for Con Edison and CECONY for the three and nine months ended September 30, 2021 and 2020.

Leases

Leases

Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Operating lease cost	$22	$21	$16	$16
Operating lease cash flows	$10	$10	$6	$6

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Operating lease cost	$65	$63	$49	$48
Operating lease cash flows	$26	$27	$15	$13

As of September 30, 2021, assets recorded as finance leases were $2 million for Con Edison and $1 million for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $2 million, respectively. As of December 31, 2020, assets recorded as finance leases were $3 million for Con Edison and $2 million for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively.

For the three and nine months ended September 30, 2021 and 2020, finance lease costs and cash flows for Con Edison and CECONY were immaterial.

Right-of-use assets obtained in exchange for operating lease obligations for Con Edison and CECONY were $15 million and $5 million, respectively, for the three months ended September 30, 2021 and $32 million and $7 million, respectively for the nine months ended September 30, 2021. Right-of-use assets obtained in exchange for operating lease obligations for Con Edison and CECONY were $8 million and $2 million, respectively, for the three months ended September 30, 2020 and $13 million and $3 million, respectively for the nine months ended September 30, 2020.

Other information related to leases for Con Edison and CECONY at September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
	2021	2020	2021	2020
Weighted Average Remaining Lease Term:
Operating leases	18.5 years	19.1 years	12.4 years	13.0 years
Finance leases	7.1 years	7.3 years	3.3 years	4.0 years
Weighted Average Discount Rate:
Operating leases	4.3%	4.3%	3.6%	3.6%
Finance leases	1.8%	1.8%	1.2%	1.3%

Future minimum lease payments under non-cancellable leases at September 30, 2021 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending September 30,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2022	$82	$1	$59	$1
2023	76	—	58	—
2024	75	—	57	—
2025	76	—	58	—
2026	75	—	58	—
All years thereafter	937	1	446	—
Total future minimum lease payments	$1,321	$2	$736	$1
Less: imputed interest	(452)	—	(144)	—
Total	$869	$2	$592	$1
Reported as of September 30, 2021
Operating lease liabilities (current)	$113	$—	$85	$—
Operating lease liabilities (noncurrent)	756	—	507	—
Other current liabilities	—	1	—	—
Other noncurrent liabilities	—	1	—	1
Total	$869	$2	$592	$1

At September 30, 2021, the Companies did not have material obligations under operating or finance leases that had not yet commenced.

The Companies are lessors under certain leases whereby the Companies own real estate and distribution poles and lease portions of them to others. Revenue under such leases was immaterial for Con Edison and CECONY for the three and nine months ended September 30, 2021 and 2020.

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Income Tax

9 Months Ended

Sep. 30, 2021

Income Tax Disclosure [Abstract]

Income Tax

Income Tax

Con Edison’s income tax expense increased to $127 million for the three months ended September 30, 2021 from $119 million for the three months ended September 30, 2020. The increase in income tax expense is primarily due to lower income attributable to non-controlling interests, offset in part by lower income before income tax expense, lower state income taxes, an increase in the amortization of excess deferred federal income taxes due to the TCJA and a higher favorable tax adjustment for the prior year tax return primarily due to an increase in the general business tax credit compared with last year.

CECONY’s income tax expense decreased to $90 million for the three months ended September 30, 2021 from $97 million for the three months ended September 30, 2020. The decrease in income tax expense is primarily due to an increase in the amortization of excess deferred federal income taxes due to the TCJA and a higher favorable tax adjustment for the prior year tax return primarily due to an increase in the general business tax credit compared with last year, offset in part by higher income before income tax expense and lower flow-through tax benefits in 2021 for plant-related items.

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 September 30, 2021 and 2020 is as follows:

	Con Edison				CECONY
(% of Pre-tax income)	2021		2020		2021		2020
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income tax, net of federal income tax benefit	5		6		5		5
Amortization of excess deferred federal income taxes	(7)		(7)		(8)		(8)
Taxes attributable to non-controlling interests	4		(1)		—		—
Cost of removal	1		1		1		2
Other plant-related items	(1)		(1)		(1)		(1)
Renewable energy credits	(1)		(1)		—		—
Injuries and damages reserve	—		—		1		—
Prior period federal income tax return adjustments	(1)		—		(1)		—
Other	—		1		—		—
Effective tax rate	21	%	19	%	18	%	19	%

Con Edison’s income tax expense increased to $194 million for the nine months ended September 30, 2021 from $183 million for the nine months ended September 30, 2020. The increase in income tax expense is primarily due to lower income attributable to non-controlling interests, offset in part by lower income before income tax expense, lower state income taxes, an increase in the amortization of excess deferred federal income taxes due to the TCJA and a higher favorable tax adjustment for the prior year tax return primarily due to an increase in the general business tax credit compared with last year.

CECONY’s income tax expense decreased to $188 million for the nine months ended September 30, 2021 from $199 million for the nine months ended September 30, 2020. The decrease in income tax expense is primarily due to an increase in the amortization of excess deferred federal income taxes due to the TCJA, a higher favorable tax adjustment for the prior year tax return primarily due to an increase in the general business tax credit compared with last year, the absence of the amortization of excess deferred state income taxes in 2021, offset in part by higher income before income tax expense and lower flow-through tax benefits in 2021 for plant-related items.

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 nine months ended September 30, 2021 and 2020 is as follows:

	Con Edison				CECONY
(% of Pre-tax income)	2021		2020		2021		2020
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income tax, net of federal income tax benefit	5		5		5		5
Amortization of excess deferred federal income taxes	(11)		(10)		(11)		(10)
Taxes attributable to non-controlling interests	3		(1)		—		—
Cost of removal	2		2		2		2
Other plant-related items	(1)		(1)		(1)		(2)
Renewable energy credits	(2)		(2)		—		—
Other	(1)		—		—		1
Effective tax rate	16	%	14	%	16	%	17	%

In response to the economic impacts of the COVID-19 pandemic, the Coronavirus Aid, Relief, and Economic Security Act (CARES Act) was signed into law on March 27, 2020. The CARES Act provides relief to corporate taxpayers by permitting a five-year carryback of net operating losses (NOLs) for tax years 2018, 2019 and 2020, temporarily removing the 80 percent limitation when applying the NOLs to carryback years, increasing the 30 percent limitation on interest deductibility to 50 percent of adjusted taxable income for tax years 2019 and 2020, and provides for certain employee retention tax credits and refunds for eligible employers.

Under the CARES Act, Con Edison carried back its $29 million NOL from tax year 2018 to tax year 2013 generating a $2.5 million net tax refund for which a tax receivable was established in 2020. In addition, Con Edison recognized a discrete income tax benefit of $4 million in 2020, due to the higher federal statutory tax rate in 2013. The 2018 federal NOL was recorded at 21 percent and will be carried back to tax year 2013, which had a 35 percent federal statutory tax rate. This tax benefit was primarily recognized at the Clean Energy Businesses.

Pursuant to CECONY’s electric rate plan that went into effect in January 2020, the deferral of its net benefits for its electric service ceased and is included in rates. Additionally, the unprotected excess deferred federal income taxes for its electric and gas services is being amortized over a five-year period, which decreased the income tax expense for the nine months ended September 30, 2021 and 2020. See “Other Regulatory Matters” in Note B.

In April 2021, New York State passed a law that increased the corporate franchise tax rate on business income from 6.5% to 7.25%, retroactive to January 1, 2021, for taxpayers with taxable income greater than $5 million. The law also reinstated the business capital tax at 0.1875%, not to exceed an annual maximum tax liability of $5 million per taxpayer. New York State requires a corporate franchise taxpayer to calculate and pay the highest amount of tax under the three alternative methods: a tax on business income; a tax on business capital; or a fixed dollar minimum. The provisions to increase the corporate franchise tax rate and reinstate a business capital tax are scheduled to expire after 2023 and are not expected to have a material impact on the Companies’ financial position, results of operations or liquidity.

Uncertain Tax Positions

At September 30, 2021, the estimated liability for uncertain tax positions for Con Edison was $17 million ($6 million for CECONY). Con Edison reasonably expects to resolve within the next twelve months approximately $3 million of various federal and state uncertainties due to the expected completion of ongoing tax examinations, of which the entire amount, if recognized, would reduce Con Edison's effective tax rate. The amount related to CECONY is $1 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 $17 million ($16 million, net of federal taxes) with $6 million attributable to CECONY.

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. For the nine months ended September 30, 2021, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At September 30, 2021 and December 31, 2020, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

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Revenue Recognition

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Revenue Recognition

Revenue Recognition

The following table presents, for the three and nine months ended September 30, 2021 and 2020, revenue from contracts with customers as defined in Accounting Standards Codification 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 September 30, 2021			For the Three Months Ended September 30, 2020
(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	$2,776	$(46)	$2,730	$2,594	$(32)	$2,562
Gas	305	2	307	248	11	259
Steam	52	3	55	50	1	51
Total CECONY	$3,133	$(41)	$3,092	$2,892	$(20)	$2,872
O&R
Electric	229	(6)	223	210	(2)	208
Gas	32	2	34	27	3	30
Total O&R	$261	$(4)	$257	$237	$1	$238
Clean Energy Businesses
Renewables	199	—	199	194	—	194
Energy services	65	—	65	14	—	14
Other	—	—	—	—	14	14
Total Clean Energy Businesses	$264	$0	$264	$208	$14	$222
Con Edison Transmission	1	—	1	1	—	1
Other (b)	—	(1)	(1)	—	—	—
Total Con Edison	$3,659	$(46)	$3,613	$3,338	$(5)	$3,333

(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)    Parent company and consolidation adjustments.

	For the Nine Months Ended September 30, 2021			For the Nine Months Ended September 30, 2020
(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	$6,695	$(34)	$6,661	$6,108	$70	$6,178
Gas	1,699	31	1,730	1,480	29	1,509
Steam	383	10	393	375	10	385
Total CECONY	$8,777	$7	$8,784	$7,963	$109	$8,072
O&R
Electric	535	(13)	522	478	5	483
Gas	184	(7)	177	156	8	164
Total O&R	$719	$(20)	$699	$634	$13	$647
Clean Energy Businesses
Renewables	545	—	545	487	—	487
Energy services	168	—	168	36	—	36
Other	—	66	66	—	43	43
Total Clean Energy Businesses	$713	$66	$779	$523	$43	$566
Con Edison Transmission	3	—	3	3	—	3
Other (b)	—	(4)	(4)	—	(2)	(2)
Total Con Edison	$10,212	$49	$10,261	$9,123	$163	$9,286

(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)    Parent company and consolidation adjustments.

	2021			2020
(Millions of Dollars)	Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)
Beginning balance as of January 1,	$11	$41		$29	$17
Additions (c)	174	—		74	31
Subtractions (c)	127	31	(d)	90	4	(d)
Ending balance as of September 30,	$58	$10		$13	$44

(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, $31 million and $4 million were included in the balances as of January 1, 2021 and 2020, respectively.

As of September 30, 2021, the aggregate amount of the remaining fixed performance obligations of the Clean Energy Businesses under contracts with customers for energy services is $187 million, of which $148 million will be recognized within the next two years, and the remaining $39 million will be recognized pursuant to long-term service and maintenance agreements.

In March 2020, the Utilities began suspending new late payment charges and certain other fees for all customers. For the three months ended September 30, 2021, the estimated late payment charges and fees that were not billed by Con Edison and CECONY were approximately $12 million and $11 million lower than the amounts that were approved to be collected pursuant to the Utilities’ rate plans, respectively. For the nine months ended September 30, 2021, the estimated late payment charges and fees that were not billed by Con Edison and CECONY were approximately $49 million and $46 million lower than the amounts that were approved to be collected pursuant to the Utilities’ rate plans, respectively. For the three months ended September 30, 2020, the estimated late payment charges and fees that were not billed by Con Edison and CECONY were approximately $18 million and $17 million lower than the amounts that were approved to be collected pursuant to the Utilities’ rate plans, respectively. For the nine months ended September 30, 2020, the estimated late payment charges and fees that were not billed by Con Edison and CECONY were approximately $38 million and $36 million lower than the amounts that were approved to be collected pursuant to the Utilities’ rate plans, respectively. The Utilities also began providing payment extensions for all customers that were scheduled to be disconnected prior to the start of the COVID-19 pandemic. In April 2021, CECONY filed a petition with the NYSPSC to timely establish a surcharge recovery mechanism for $52 million of late payment charges and fees, offset for related savings, for the year ended December 31, 2020 to begin in September 2021 and end in December 2022. The petition also requests a surcharge recovery or surcredit mechanism for any fee deferrals for 2021 and 2022 starting in January of the subsequent year over a twelve-month period, respectively. See "COVID-19 Regulatory Matters" in Note B.

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Current Expected Credit Losses

9 Months Ended

Sep. 30, 2021

Credit Loss [Abstract]

Current Expected Credit Losses

Current Expected Credit Losses

In January 2020, the Companies adopted Accounting Standards Update (ASU) 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments”.

Allowance for Uncollectible Accounts

The Utilities’ “Account receivable – customers” balance consists of utility bills due (bills are generally due the month following billing) from customers who have energy delivered, generated, or services provided by the Utilities. The balance also reflects the Utilities’ purchase of receivables from energy service companies to support the retail choice programs.

“Other receivables” balance generally reflects costs billed by the Utilities for goods and services provided to external parties, such as accommodation work for private parties and certain governmental entities, real estate rental and pole attachments. The Clean Energy Businesses’ other receivables balance includes bills related to the sale of energy from renewable electric production projects.

The Clean Energy Businesses’ customer accounts receivable balance generally reflects the management of energy supply assets, energy-efficiency services to government and commercial customers, and the engineering, procurement, and construction services of renewable energy projects. The Clean Energy Businesses calculate an allowance for uncollectible accounts related to their energy services customers based on an aging and customer-specific analysis. The amount of such reserves was not material at September 30, 2021 or December 31, 2020.

The Companies develop expected loss estimates using past events data and consider current conditions and future reasonable and supportable forecasts. Changes to the Utilities’ reserve balances that result in write-offs of customer accounts receivable balances above existing rate allowances are not reflected in rates during the term of the current rate plans. For the Utilities’ customer accounts receivable allowance for uncollectible accounts, past events considered include write-offs relative to customer accounts receivable; current conditions include macro-and micro-economic conditions related to trends in the local economy and bankruptcy rates and aged customer accounts receivable balances, among other factors; and forecasts about the future include assumptions related to the level of write-offs and recoveries. Generally, the Utilities write off customer accounts receivable as uncollectible 90 days after the account is turned off for non-payment, or the account is closed during the collection process. See "COVID-19 Regulatory Matters" in Note B.

Other receivables allowance for uncollectible accounts is calculated based on a historical average of collections relative to total other receivables, including current receivables. Current macro- and micro-economic conditions are also considered when calculating the current reserve. Probable outcomes of pending litigation, whether favorable or unfavorable to the Companies, are also included in the consideration.

Starting in 2020, the potential economic impact of the COVID-19 pandemic was also considered in forward-looking projections related to write-off and recovery rates and resulted in increases to the allowance for uncollectible accounts. The increases to the allowance for uncollectible customer accounts for Con Edison and CECONY were $38 million for the three months ended September 30, 2021 and $165 million and $162 million, respectively, for the nine months ended September 30, 2021. The increases to the allowance for uncollectible customer accounts for Con Edison and CECONY were $31 million and $30 million, respectively, for the three months ended September 30, 2020 and $48 million and $46 million, respectively, for the nine months ended September 30, 2020.

Customer accounts receivable and the associated allowance for uncollectible accounts are included in the line “Accounts receivable – customers” on the Companies’ consolidated balance sheets. Other receivables and the associated allowance for uncollectible accounts are included in “Other receivables” on the consolidated balance sheets.

The table below presents a rollforward by major portfolio segment type for the three and nine months ended September 30, 2021 and 2020:

	For the Three Months Ended September 30,
	Con Edison				CECONY
	Accounts receivable - customers		Other receivables		Accounts receivable - customers		Other receivables
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
Allowance for credit losses
Beginning Balance at July 1,	$275	$87	$7	$5	$262	$81	$4	$3
Recoveries	3	2	—	—	3	2	—	—
Write-offs	(24)	(4)	—	—	(23)	(3)	—	—
Reserve adjustments	59	33	—	1	58	31	1	1
Ending Balance September 30,	$313	$118	$7	$6	$300	$111	$5	$4

	For the Nine Months Ended September 30,
	Con Edison				CECONY
	Accounts receivable - customers		Other receivables		Accounts receivable - customers		Other receivables
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
Allowance for credit losses
Beginning Balance at January 1,	$148	$70	$7	$4	$138	$65	$4	$3
Recoveries	9	6	—	—	8	6	—	—
Write-offs	(66)	(37)	(1)	(1)	(62)	(35)	—	—
Reserve adjustments	222	79	1	3	216	75	1	1
Ending Balance September 30,	$313	$118	$7	$6	$300	$111	$5	$4

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Financial Information by Business Segment

9 Months Ended

Sep. 30, 2021

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 and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Operating revenues		Inter-segment revenues		Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
CECONY
Electric	$2,730	$2,562	$5	$4	$324	$305	$834	$813
Gas	307	259	2	2	82	74	(48)	(34)
Steam	55	51	18	18	23	22	(58)	(57)
Consolidation adjustments	—	—	(25)	(24)	—	—	—	—
Total CECONY	$3,092	$2,872	$—	$—	$429	$401	$728	$722
O&R
Electric	$223	$208	$—	$—	$18	$17	$55	$58
Gas	34	30	—	—	6	6	(8)	(9)
Total O&R	$257	$238	$—	$—	$24	$23	$47	$49
Clean Energy Businesses	$264	$222	$—	$—	$58	$58	$79	$92
Con Edison Transmission	1	1	—	—	—	—	(2)	(2)
Other (a)	(1)	—	—	—	1	—	(2)	(1)
Total Con Edison	$3,613	$3,333	$—	$—	$512	$482	$850	$860

(a) Parent company and consolidation adjustments. Other does not represent a business segment.

	For the Nine Months Ended September 30,
	Operating revenues		Inter-segment revenues		Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
CECONY
Electric	$6,661	$6,178	$14	$13	$959	$904	$1,337	$1,413
Gas	1,730	1,509	6	5	239	216	490	440
Steam	393	385	55	56	69	67	9	1
Consolidation adjustments	—	—	(75)	(74)	—	—	—	—
Total CECONY	$8,784	$8,072	$—	$—	$1,267	$1,187	$1,836	$1,854
O&R
Electric	$522	$483	$—	$—	$52	$48	$78	$86
Gas	177	164	—	—	19	19	30	28
Total O&R	$699	$647	$—	$—	$71	$67	$108	$114
Clean Energy Businesses	$779	$566	$—	$—	$172	$173	$196	$188
Con Edison Transmission	3	3	—	—	1	1	(7)	(6)
Other (a)	(4)	(2)	—	—	—	—	(4)	(3)
Total Con Edison	$10,261	$9,286	$—	$—	$1,511	$1,428	$2,129	$2,147

(a) Parent company and consolidation adjustments. Other does not represent a business segment.

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Derivative Instruments and Hedging Activities

9 Months Ended

Sep. 30, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging ActivitiesCon 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. These are economic hedges, for which the Utilities and the Clean Energy Business do not elect hedge accounting. The Clean Energy Businesses use interest rate swaps to manage the risks associated with interest rates related to outstanding and expected future debt issuances and borrowings. Derivatives are recognized on the consolidated balance sheet at fair value (see Note O), 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.

The fair values of the Companies’ derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at September 30, 2021 and December 31, 2020 were:

(Millions of Dollars)	2021				2020
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	$652	$(375)	$277	(b)	$44	$14	$58	(b)
Noncurrent	140	(15)	125	(c)	22	35	57
Total fair value of derivative assets	$792	$(390)	$402		$66	$49	$115
Fair value of derivative liabilities
Current	$(428)	$265	$(163)	(c)	$(225)	$(13)	$(238)	(d)
Noncurrent	(183)	17	(166)	(c)	(207)	(33)	(240)	(d)
Total fair value of derivative liabilities	$(611)	$282	$(329)		$(432)	$(46)	$(478)
Net fair value derivative assets/(liabilities)	$181	($108)	$73		$(366)	$3	$(363)
CECONY
Fair value of derivative assets
Current	$407	$(183)	$224	(b)	$20	$(12)	$8	(b)
Noncurrent	114	(28)	86		16	(8)	8
Total fair value of derivative assets	$521	$(211)	$310		$36	$(20)	$16
Fair value of derivative liabilities
Current	$(158)	$44	$(114)		$(174)	$11	$(163)
Noncurrent	(125)	28	(97)		(114)	9	(105)
Total fair value of derivative liabilities	$(283)	$72	$(211)		$(288)	$20	$(268)
Net fair value derivative assets/(liabilities)	$238	$(139)	$99		$(252)	$—	$(252)

(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 September 30, 2021, immaterial amounts of margin deposits for Con Edison and CECONY were classified as derivative assets on the consolidated balance sheet, but not included in the table. At December 31, 2020, margin deposits for Con Edison and CECONY of $3 million 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)Includes amounts for interest rate swaps of $5 million in noncurrent assets, $(26) million in current liabilities and $(39) million in noncurrent liabilities. At September 30, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,046 million. The expiration dates of the swaps range from 2025-2041. In June 2021, as part of the Clean Energy Businesses' sale of a renewable electric project, interest rate swaps terminating in 2024 were assumed by the buyer.

(d)Includes amounts for interest rate swaps of $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps ranged from 2024-2041.

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 regulatory 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 gas purchased for resale and non-utility revenue in the reporting period in which they occur. The Clean Energy Businesses record changes in the fair value of their interest rate swaps in other interest expense at the end of each reporting period. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices and interest rates.

The following table presents the realized and unrealized gains or losses on derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2021 and 2020:

		For the Three Months Ended September 30,
		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2021	2020	2021	2020
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$296	$26	$279	$24
Noncurrent	Deferred derivative gains	70	17	66	16
Total deferred gains/(losses)		$366	$43	$345	$40
Current	Deferred derivative losses	$(4)	$(9)	$(3)	$(11)
Current	Recoverable energy costs	17	(23)	13	(19)
Noncurrent	Deferred derivative losses	(61)	(15)	(55)	(12)
Total deferred gains/(losses)		($48)	$(47)	$(45)	$(42)
Net deferred gains/(losses)		$318	$(4)	$300	$(2)
	Income Statement Location
Pre-tax gains/(losses) recognized in income
	Gas purchased for resale	$2	$—	$—	$—
	Non-utility revenue	(23)	(2)	—	—
	Other operations and maintenance expense	1	—	1	—
	Other interest expense	11	7	—	—
Total pre-tax gains/(losses) recognized in income		$(9)	$5	$1	$—

		For the Nine Months Ended September 30,
		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2021	2020	2021	2020
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$443	$23	$415	$20
Noncurrent	Deferred derivative gains	106	15	97	14
Total deferred gains/(losses)		$549	$38	$512	$34
Current	Deferred derivative losses	$25	$12	$22	$9
Current	Recoverable energy costs	(30)	(163)	(29)	(144)
Noncurrent	Deferred derivative losses	(16)	(73)	(13)	(70)
Total deferred gains/(losses)		$(21)	$(224)	$(20)	$(205)
Net deferred gains/(losses)		$528	$(186)	$492	$(171)
	Income Statement Location
Pre-tax gains/(losses) recognized in income
	Gas purchased for resale	$4	$(3)	$—	$—
	Non-utility revenue	(22)	3	—	—
	Other operations and maintenance expense	5	(5)	5	(5)
	Other interest expense	45	(82)	—	—
Total pre-tax gains/(losses) recognized in income		$32	$(87)	$5	$(5)

The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at September 30, 2021:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	23,870,400	39,914	280,838,997	4,704,000
CECONY	21,401,150	29,700	261,010,000	4,704,000

(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 September 30, 2021, Con Edison and CECONY had $689 million and $424 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 $95 million with independent system operators, $103 million with non-investment grade/non-rated counterparties, $160 million with commodity exchange brokers, and $331 million with investment-grade counterparties. CECONY’s net credit exposure consisted of $131 million with commodity exchange brokers and $293 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 September 30, 2021:

(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$211		$176
Collateral posted	170		165
Additional collateral (b) (downgrade one level from current ratings)	24		4
Additional collateral (b) (downgrade to below investment grade from current ratings)	83	(c)	54	(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 $14 million of additional collateral at September 30, 2021. 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 September 30, 2021, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $72 million.

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Fair Value Measurements

9 Months Ended

Sep. 30, 2021

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 September 30, 2021 and December 31, 2020 are summarized below.

	2021					2020
(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)	$215	$533	$29	$(380)	$397	$19	$42	$4	$53	$118
Interest rate swaps (a)(b)(c)	—	5	—	—	5	—	—	—	—	—
Other (a)(b)(d)	479	136	—	—	615	431	126	—	—	557
Total assets	$694	$674	$29	$(380)	$1,017	$450	$168	$4	$53	$675
Derivative liabilities:
Commodity (a)(b)(c)	$40	$462	$34	$(272)	$264	$7	$296	$23	$46	$372
Interest rate swaps (a)(b)(c)	—	65	—	—	65	—	106	—	—	106
Total liabilities	$40	$527	$34	$(272)	$329	$7	$402	$23	$46	$478
CECONY
Derivative assets:
Commodity (a)(b)(c)	$142	$367	$2	$(201)	$310	$15	$20	$—	$(16)	$19
Other (a)(b)(d)	460	128	—	—	588	411	120	—	—	531
Total assets	$602	$495	$2	$(201)	$898	$426	$140	$—	$(16)	$550
Derivative liabilities:
Commodity (a)(b)(c)	$—	$253	$19	$(61)	$211	$3	$274	$10	$(19)	$268

(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 nine months ended September 30, 2021. Con Edison and CECONY had $1 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2020 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2020 to less than three years as of December 31, 2020.

(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, and 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 September 30, 2021 and December 31, 2020, 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.

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 and interest rate swaps. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives and interest rate swaps. Fair value and changes in fair value of commodity derivatives and interest rate swaps 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 September 30, 2021	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
Con Edison – Commodity
Electricity	$11	Discounted Cash Flow	Forward energy prices (a)	$15.00-$130.75 per MWh
	(17)	Discounted Cash Flow	Forward capacity prices (a)	$0.26-$12.93 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(4.21)-$10.11 per MWh
Total Con Edison—Commodity	$(5)
CECONY – Commodity
Electricity	$(9)	Discounted Cash Flow	Forward energy prices (a)	$26.80-$98.51 per MWh
	(10)	Discounted Cash Flow	Forward capacity prices (a)	$0.70-$12.93 per kW-month
Transmission Congestion Contracts	2	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.63-$5.63 per MWh
Total CECONY—Commodity	$(17)

(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 September 30, 2021 and 2020 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance as of July 1,	$(9)	$(14)	$(7)	$(7)
Included in earnings	21	—	1	—
Included in regulatory assets and liabilities	(17)	(3)	(11)	(1)
Settlements	—	—	—	(1)
Ending balance as of September 30,	$(5)	$(17)	$(17)	$(9)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance as of January 1,	$(19)	$(16)	$(10)	$(6)
Included in earnings	20	(7)	(2)	(3)
Included in regulatory assets and liabilities	(9)	(3)	(7)	(3)
Settlements	3	9	2	3
Ending balance as of September 30,	$(5)	$(17)	$(17)	$(9)

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 on the consolidated income statement for the three months ended September 30, 2021 and 2020 ($20 million gain and $1 million gain, respectively). Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues on the consolidated income statement for the nine months ended September 30, 2021 and 2020 ($24 million gain and $2 million gain, respectively).

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Variable Interest Entities

9 Months Ended

Sep. 30, 2021

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 2020, 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.

Clean Energy Businesses

In June 2021, a subsidiary of the Clean Energy Businesses sold substantially all of its membership interest in a renewable electric project, and retained an equity interest of $11 million in the project which, as of September 30, 2021, is valued at $7 million and is accounted for as an equity method investment. See Note R. The earnings of the project are determined using the hypothetical liquidation at book value (HLBV) method of accounting, and such earnings were not material for the three and nine months ended September 30, 2021. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the renewable electric project is not held by the Clean Energy Businesses.

In February 2021, a subsidiary of the Clean Energy Businesses entered into an agreement relating to certain projects (CED Nevada Virginia) with a noncontrolling tax equity investor to which a percentage of earnings, tax attributes and cash flows will be allocated. CED Nevada Virginia is a consolidated entity 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 CED Nevada Virginia during construction of the projects, and upon commercial operation, is held by the Clean Energy Businesses.

For the three months ended September 30, 2021, the hypothetical liquidation at book value (HLBV) method of accounting for CED Nevada Virginia resulted in a $74 million loss ($56 million, after-tax) for the tax equity investor and an equivalent amount of income for Con Edison.

For the nine months ended September 30, 2021, the HLBV method of accounting for CED Nevada Virginia resulted in a $127 million loss ($96 million, after tax) for the tax equity investor and an equivalent amount of income for Con Edison.

In December 2018, the Clean Energy Businesses 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 the Clean Energy Businesses. 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 September 30, 2021, the HLBV method of accounting for the Tax Equity Projects resulted in an immaterial amount of income for the tax equity investor and $14 million of income ($11 million, after-tax) for Con Edison. For the three months ended September 30, 2020, the HLBV method of accounting for the Tax Equity Projects resulted in $9 million of income ($7 million, after-tax) for the tax equity investor and $7 million of income ($5 million, after-tax) for Con Edison.

For the nine months ended September 30, 2021, the HLBV method of accounting for the Tax Equity Projects resulted in $8 million of income ($6 million, after tax) for the tax equity investor and $27 million of income ($20 million, after tax) for Con Edison. For the nine months ended September 30, 2020, the HLBV method of accounting for the Tax Equity Projects resulted in $38 million of income ($29 million, after tax) for the tax equity investor and a $3 million loss ($2 million, after tax) for Con Edison.

Con Edison has determined that the use of HLBV accounting is reasonable and appropriate to attribute income and loss to the tax equity investors. Using the HLBV method, the company's earnings from the projects are adjusted to reflect the income or loss allocable to the tax equity investors calculated based on how the project would allocate and distribute its cash if it were to sell all of its assets for their carrying amounts and liquidate at a particular point in time. Under the HLBV method, the company calculates the liquidation value allocable to the tax equity investors at the beginning and end of each period based on the contractual liquidation waterfall and adjusts its income for the period to reflect the change in the liquidation value allocable to the tax equity investors.

At September 30, 2021 and December 31, 2020, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs:

	Tax Equity Projects
	Great Valley Solar (c)(d)		Copper Mountain - Mesquite Solar  (c)(e)		CED Nevada Virginia (c)(h)
(Millions of Dollars)	2021	2020	2021	2020	2021
Non-utility property, less accumulated depreciation (f)(g)	$278	$284	$435	$446	$647
Other assets	40	39	174	176	57
Total assets (a)	$318	$323	$609	$622	$704
Other liabilities	14	13	79	71	328
Total liabilities (b)	$14	$13	$79	$71	$328

(a)The assets of the Tax Equity Projects and CED Nevada Virginia 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 CED Nevada Virginia 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 $88 million and $82 million at September 30, 2021 and December 31, 2020, 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 $122 million and $134 million at September 30, 2021 and December 31, 2020, respectively.

(f)Non-utility property is reduced by accumulated depreciation of $24 million for Great Valley Solar, $40 million for Copper Mountain - Mesquite Solar, and $5 million for CED Nevada Virginia at September 30, 2021.

(g)Non-utility property is reduced by accumulated depreciation of $18 million for Great Valley Solar and $30 million for Copper Mountain - Mesquite Solar at December 31, 2020.

(h)CED Nevada Virginia consists of the Copper Mountain Solar 5, Battle Mountain Solar and Water Strider Solar projects for which the noncontrolling interest of the tax equity investor was $128 million at September 30, 2021.

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New Financial Accounting Standards	9 Months Ended
	Sep. 30, 2021
Accounting Changes and Error Corrections [Abstract]
New Financial Accounting Standards	New Financial Accounting StandardsIn March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (ASU 2020-04). In 2017, the United Kingdom’s Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit the London Interbank Offered Rate (LIBOR), a benchmark interest rate referenced in a variety of agreements, after 2021. In March 2021, the United Kingdom's Financial Conduct Authority confirmed that U.S. Dollar LIBOR will no longer be published after December 31, 2021 for one-week and two-month U.S. Dollar LIBOR tenors, and after June 30, 2023 for all other U.S. Dollar LIBOR tenors. ASU 2020-04 provides entities with optional expedients and exceptions for applying generally accepted accounting principles to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another reference rate expected to be discontinued. In January 2021, the FASB issued amendments to the guidance through ASU 2021-01 to include all contract modifications and hedging relationships affected by reference rate reform, including those that do not directly reference LIBOR or another reference rate expected to be discontinued, and clarify which optional expedients may be applied to them. The guidance can be applied prospectively. The optional relief is temporary and generally cannot be applied to contract modifications and hedging relationships entered into or evaluated after December 31, 2022. The Companies do not expect the new guidance to have a material impact on their financial position, results of operations or liquidity.

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Dispositions

9 Months Ended

Sep. 30, 2021

Discontinued Operations and Disposal Groups [Abstract]

Dispositions

Dispositions

In April 2021, a subsidiary of the Clean Energy Businesses entered into an agreement to sell substantially all of its membership interests in a renewable electric project that it developed and also all of its membership interests in a renewable electric production project that it acquired in 2016. The sales were completed in June 2021. The combined carrying value of both projects was approximately $180 million in June 2021. The net pre-tax gain on the sales was $3 million ($2 million after-tax) and was included within "Other operations and maintenance" on Con Edison's consolidated income statement for the nine months ended September 30, 2021. The retained portion of the membership interest in the renewable electric project, of $11 million, was calculated based on a discounted cash flow of future projected earnings, and the retained portion is accounted for as an equity method investment. The portion of the gain attributable to the retained portion of the membership interest was not material for the nine months ended September 30, 2021. See Note P.

In July 2021, a subsidiary of CET Gas and its joint venture partner completed the first of two closings for the sale of their combined interests in Stagecoach. The first closing was completed for a total sale price of $1,195 million, of which $614 million, including working capital, was attributed to CET Gas. See "Investments" in Note A.

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Summary of Significant Accounting Policies and Other Matters (Policies)

9 Months Ended

Sep. 30, 2021

Accounting Policies [Abstract]

Reclassification

Reclassification

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

Earnings Per Common Share

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 is 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.

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.

New Financial Accounting Standards

New Financial Accounting StandardsIn March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (ASU 2020-04). In 2017, the United Kingdom’s Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit the London Interbank Offered Rate (LIBOR), a benchmark interest rate referenced in a variety of agreements, after 2021. In March 2021, the United Kingdom's Financial Conduct Authority confirmed that U.S. Dollar LIBOR will no longer be published after December 31, 2021 for one-week and two-month U.S. Dollar LIBOR tenors, and after June 30, 2023 for all other U.S. Dollar LIBOR tenors. ASU 2020-04 provides entities with optional expedients and exceptions for applying generally accepted accounting principles to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another reference rate expected to be discontinued. In January 2021, the FASB issued amendments to the guidance through ASU 2021-01 to include all contract modifications and hedging relationships affected by reference rate reform, including those that do not directly reference LIBOR or another reference rate expected to be discontinued, and clarify which optional expedients may be applied to them. The guidance can be applied prospectively. The optional relief is temporary and generally cannot be applied to contract modifications and hedging relationships entered into or evaluated after December 31, 2022. The Companies do not expect the new guidance to have a material impact on their financial position, results of operations or liquidity.

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Summary of Significant Accounting Policies and Other Matters (Tables)

9 Months Ended

Sep. 30, 2021

Accounting Policies [Abstract]

Basic and Diluted Earnings Per Share

For the three and nine months ended September 30, 2021 and 2020, basic and diluted EPS for Con Edison were calculated as follows:

	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2021	2020	2021	2020
Net income for common stock	$538	$493	$1,122	$1,058
Weighted average common shares outstanding – basic	353.4	334.5	346.8	334.1
Add: Incremental shares attributable to effect of potentially dilutive securities	0.7	0.9	0.7	0.9
Adjusted weighted average common shares outstanding – diluted	354.1	335.4	347.5	335.0
Net Income per common share – basic	$1.52	$1.47	$3.23	$3.17
Net Income per common share – diluted	$1.52	$1.47	$3.23	$3.16

Changes in Accumulated Other Comprehensive Income/(Loss)

For the three and nine months ended September 30, 2021 and 2020, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance, accumulated OCI, net of taxes (a)	$(19)	$(14)	$(7)	$(4)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2021 and 2020 (a)(b)	2	2	—	—
Current period OCI, net of taxes	2	2	—	—
Ending balance, accumulated OCI, net of taxes (a)	$(17)	$(12)	$(7)	$(4)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance, accumulated OCI, net of taxes (a)	$(25)	$(19)	$(7)	$(6)
OCI before reclassifications, net of tax of $(1) for Con Edison in 2021 and 2020	2	4	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2021 and 2020 (a)(b)	6	3	—	2
Current period OCI, net of taxes	8	7	—	2
Ending balance, accumulated OCI, net of taxes (a)	$(17)	$(12)	$(7)	$(4)

(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 and liabilities 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 costs. See Notes E and F.

Restrictions on Cash and Cash Equivalents

At September 30, 2021 and 2020, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows:

	At September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Cash and temporary cash investments	$66	$153	$18	$23
Restricted cash (a)	149	161	—	—
Total cash, temporary cash investments and restricted cash	$215	$314	$18	$23

(a)Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($149 million and $161 million at September 30, 2021 and 2020, respectively) that, under the related project debt agreements, is restricted to being used for normal operating expenses and capital expenditures, debt service, and required reserves until the various maturity dates of the project debt.

Schedule of Cash and Cash Equivalents

At September 30, 2021 and 2020, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows:

	At September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Cash and temporary cash investments	$66	$153	$18	$23
Restricted cash (a)	149	161	—	—
Total cash, temporary cash investments and restricted cash	$215	$314	$18	$23

(a)Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($149 million and $161 million at September 30, 2021 and 2020, respectively) that, under the related project debt agreements, is restricted to being used for normal operating expenses and capital expenditures, debt service, and required reserves until the various maturity dates of the project debt.

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Regulatory Matters (Tables)

9 Months Ended

Sep. 30, 2021

Regulated Operations [Abstract]

Schedule of Regulatory Assets

Regulatory assets and liabilities at September 30, 2021 and December 31, 2020 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Regulatory assets
Unrecognized pension and other postretirement costs	$2,527	$3,241	$2,394	$3,065
Environmental remediation costs	846	865	780	791
Pension and other postretirement benefits deferrals	438	315	382	272
Revenue taxes	385	356	369	342
COVID-19 pandemic deferrals	274	115	269	113
Deferred storm costs	277	195	155	83
Property tax reconciliation	245	241	245	239
MTA power reliability deferral	152	188	152	188
System peak reduction and energy efficiency programs	145	124	145	124
Deferred derivative losses - long term	136	120	124	111
Municipal infrastructure support costs	49	62	49	62
Brooklyn Queens demand management program	35	36	35	36
Meadowlands heater odorization project	30	32	30	32
Preferred stock redemption	20	21	20	21
Non-wire alternative projects	23	18	23	18
Unamortized loss on reacquired debt	17	21	15	19
Recoverable REV demonstration project costs	15	20	14	18
Gate station upgrade project	15	25	15	25
Other	274	200	257	186
Regulatory assets – noncurrent	5,903	6,195	5,473	5,745
Deferred derivative losses - short term	166	190	155	177
Recoverable energy costs	39	76	32	67
Regulatory assets – current	205	266	187	244
Total Regulatory Assets	$6,108	$6,461	$5,660	$5,989
Regulatory liabilities
Future income tax	$2,040	$2,207	$1,896	$2,062
Allowance for cost of removal less salvage	1,114	1,090	950	932
Net unbilled revenue deferrals	184	198	184	198
TCJA net benefits*	167	295	164	286
Net proceeds from sale of property	111	137	111	137
Deferred derivative gains - long term	110	5	101	4
Pension and other postretirement benefit deferrals	98	85	53	46
System benefit charge carrying charge	71	64	63	57
Property tax refunds	35	36	35	35
BQDM and REV Demo reconciliations	26	27	22	25
Sales and use tax refunds	18	16	17	16
Energy efficiency portfolio standard unencumbered funds	17	1	19	—
Earnings sharing - electric, gas and steam	13	15	10	10
Unrecognized other postretirement costs	12	11	—	—
Settlement of gas proceedings	11	21	11	21
Settlement of prudence proceeding	6	5	6	5
Workers' compensation	5	3	5	3
Other	341	297	294	257
Regulatory liabilities – noncurrent	4,379	4,513	3,941	4,094
Deferred derivative gains - short term	451	8	423	7
Refundable energy costs	31	28	5	4
Revenue decoupling mechanism	8	—	—	—
Regulatory liabilities – current	490	36	428	11
Total Regulatory Liabilities	$4,869	$4,549	$4,369	$4,105

* See "Other Regulatory Matters," above.

Schedule of Regulatory Liabilities

Regulatory assets and liabilities at September 30, 2021 and December 31, 2020 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Regulatory assets
Unrecognized pension and other postretirement costs	$2,527	$3,241	$2,394	$3,065
Environmental remediation costs	846	865	780	791
Pension and other postretirement benefits deferrals	438	315	382	272
Revenue taxes	385	356	369	342
COVID-19 pandemic deferrals	274	115	269	113
Deferred storm costs	277	195	155	83
Property tax reconciliation	245	241	245	239
MTA power reliability deferral	152	188	152	188
System peak reduction and energy efficiency programs	145	124	145	124
Deferred derivative losses - long term	136	120	124	111
Municipal infrastructure support costs	49	62	49	62
Brooklyn Queens demand management program	35	36	35	36
Meadowlands heater odorization project	30	32	30	32
Preferred stock redemption	20	21	20	21
Non-wire alternative projects	23	18	23	18
Unamortized loss on reacquired debt	17	21	15	19
Recoverable REV demonstration project costs	15	20	14	18
Gate station upgrade project	15	25	15	25
Other	274	200	257	186
Regulatory assets – noncurrent	5,903	6,195	5,473	5,745
Deferred derivative losses - short term	166	190	155	177
Recoverable energy costs	39	76	32	67
Regulatory assets – current	205	266	187	244
Total Regulatory Assets	$6,108	$6,461	$5,660	$5,989
Regulatory liabilities
Future income tax	$2,040	$2,207	$1,896	$2,062
Allowance for cost of removal less salvage	1,114	1,090	950	932
Net unbilled revenue deferrals	184	198	184	198
TCJA net benefits*	167	295	164	286
Net proceeds from sale of property	111	137	111	137
Deferred derivative gains - long term	110	5	101	4
Pension and other postretirement benefit deferrals	98	85	53	46
System benefit charge carrying charge	71	64	63	57
Property tax refunds	35	36	35	35
BQDM and REV Demo reconciliations	26	27	22	25
Sales and use tax refunds	18	16	17	16
Energy efficiency portfolio standard unencumbered funds	17	1	19	—
Earnings sharing - electric, gas and steam	13	15	10	10
Unrecognized other postretirement costs	12	11	—	—
Settlement of gas proceedings	11	21	11	21
Settlement of prudence proceeding	6	5	6	5
Workers' compensation	5	3	5	3
Other	341	297	294	257
Regulatory liabilities – noncurrent	4,379	4,513	3,941	4,094
Deferred derivative gains - short term	451	8	423	7
Refundable energy costs	31	28	5	4
Revenue decoupling mechanism	8	—	—	—
Regulatory liabilities – current	490	36	428	11
Total Regulatory Liabilities	$4,869	$4,549	$4,369	$4,105

* See "Other Regulatory Matters," above.

Schedule of Regulatory Assets Not Earning Return

Regulatory Assets Not Earning a Return*

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Unrecognized pension and other postretirement costs	$2,527	$3,241	$2,394	$3,065
Environmental remediation costs	832	855	765	781
Revenue taxes	364	336	349	323
Deferred derivative losses - long term	136	120	124	111
Other	56	24	56	24
Deferred derivative losses - current	166	190	155	177
Total	$4,081	$4,766	$3,843	$4,481

*This table includes regulatory assets not earning a return for which no cash outlay has been made.

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Capitalization (Tables)

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Carrying Amounts and Fair Values of Long-Term Debt

The carrying amounts and fair values of long-term debt at September 30, 2021 and December 31, 2020 were:

(Millions of Dollars)	2021		2020
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$22,280	$25,655	$22,349	$26,808
CECONY	$17,637	$20,774	$16,789	$20,974

(a)Amounts shown are net of unamortized debt expense and unamortized debt discount of $221 million and $188 million for Con Edison and CECONY, respectively, as of September 30, 2021 and $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020.

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Pension Benefits (Tables)

9 Months Ended

Sep. 30, 2021

Retirement Benefits [Abstract]

Total Periodic Benefit Costs

The components of the Companies’ total periodic benefit cost for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost – including administrative expenses	$85	$73	$80	$69
Interest cost on projected benefit obligation	118	137	111	129
Expected return on plan assets	(274)	(258)	(260)	(245)
Recognition of net actuarial loss	197	175	187	165
Recognition of prior service credit	(4)	(4)	(5)	(5)
TOTAL PERIODIC BENEFIT COST	$122	$123	$113	$113
Cost capitalized	(41)	(34)	(39)	(32)
Reconciliation to rate level	(54)	(62)	(52)	(59)
Total expense recognized	$27	$27	$22	$22

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost – including administrative expenses	$257	$220	$241	$206
Interest cost on projected benefit obligation	353	412	332	387
Expected return on plan assets	(822)	(775)	(779)	(735)
Recognition of net actuarial loss	590	524	559	496
Recognition of prior service credit	(12)	(12)	(15)	(15)
TOTAL PERIODIC BENEFIT COST	$366	$369	$338	$339
Cost capitalized	(120)	(98)	(113)	(93)
Reconciliation to rate level	(165)	(188)	(158)	(179)
Total expense recognized	$81	$83	$67	$67

The components of the Companies’ total periodic other postretirement benefit cost/(credit) for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost - including administrative expenses	$2	$5	$1	$4
Interest cost on projected other postretirement benefit obligation	7	9	6	8
Expected return on plan assets	(17)	(16)	(14)	(14)
Recognition of net actuarial loss	4	3	3	3
Recognition of prior service credit	—	(1)	—	—
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(4)	$—	$(4)	$1
Cost capitalized	(3)	(2)	(3)	(2)
Reconciliation to rate level	7	2	6	—
Total credit recognized	$—	$—	$(1)	$(1)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost - including administrative expenses	$15	$16	$11	$12
Interest cost on projected other postretirement benefit obligation	23	28	19	23
Expected return on plan assets	(51)	(49)	(41)	(41)
Recognition of net actuarial loss	17	34	13	32
Recognition of prior service credit	(2)	(3)	(1)	(1)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$2	$26	$1	$25
Cost capitalized	(9)	(7)	(7)	(5)
Reconciliation to rate level	7	(19)	2	(24)
Total credit recognized	$—	$—	$(4)	$(4)

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Other Postretirement Benefits (Tables)

9 Months Ended

Sep. 30, 2021

Retirement Benefits [Abstract]

Total Periodic Benefit Costs

The components of the Companies’ total periodic benefit cost for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost – including administrative expenses	$85	$73	$80	$69
Interest cost on projected benefit obligation	118	137	111	129
Expected return on plan assets	(274)	(258)	(260)	(245)
Recognition of net actuarial loss	197	175	187	165
Recognition of prior service credit	(4)	(4)	(5)	(5)
TOTAL PERIODIC BENEFIT COST	$122	$123	$113	$113
Cost capitalized	(41)	(34)	(39)	(32)
Reconciliation to rate level	(54)	(62)	(52)	(59)
Total expense recognized	$27	$27	$22	$22

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost – including administrative expenses	$257	$220	$241	$206
Interest cost on projected benefit obligation	353	412	332	387
Expected return on plan assets	(822)	(775)	(779)	(735)
Recognition of net actuarial loss	590	524	559	496
Recognition of prior service credit	(12)	(12)	(15)	(15)
TOTAL PERIODIC BENEFIT COST	$366	$369	$338	$339
Cost capitalized	(120)	(98)	(113)	(93)
Reconciliation to rate level	(165)	(188)	(158)	(179)
Total expense recognized	$81	$83	$67	$67

The components of the Companies’ total periodic other postretirement benefit cost/(credit) for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost - including administrative expenses	$2	$5	$1	$4
Interest cost on projected other postretirement benefit obligation	7	9	6	8
Expected return on plan assets	(17)	(16)	(14)	(14)
Recognition of net actuarial loss	4	3	3	3
Recognition of prior service credit	—	(1)	—	—
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(4)	$—	$(4)	$1
Cost capitalized	(3)	(2)	(3)	(2)
Reconciliation to rate level	7	2	6	—
Total credit recognized	$—	$—	$(1)	$(1)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Service cost - including administrative expenses	$15	$16	$11	$12
Interest cost on projected other postretirement benefit obligation	23	28	19	23
Expected return on plan assets	(51)	(49)	(41)	(41)
Recognition of net actuarial loss	17	34	13	32
Recognition of prior service credit	(2)	(3)	(1)	(1)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$2	$26	$1	$25
Cost capitalized	(9)	(7)	(7)	(5)
Reconciliation to rate level	7	(19)	2	(24)
Total credit recognized	$—	$—	$(4)	$(4)

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Environmental Matters (Tables)

9 Months Ended

Sep. 30, 2021

Environmental Remediation Obligations [Abstract]

Accrued Liabilities and Regulatory Assets

The accrued liabilities and regulatory assets related to Superfund Sites at September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Accrued Liabilities:
Manufactured gas plant sites	$737	$752	$662	$676
Other Superfund Sites	104	105	103	104
Total	$841	$857	$765	$780
Regulatory assets	$846	$865	$780	$791

Environmental Remediation Costs

Environmental remediation costs incurred related to Superfund Sites for the three and nine months ended September 30, 2021 and 2020 were as follows: 

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Remediation costs incurred	$7	$8	$7	$8

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Remediation costs incurred	$21	$17	$20	$16

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 or liabilities for the Companies at September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$68	$72	$65	$68
Regulatory liability – workers’ compensation	$5	$3	$5	$3

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Other Material Contingencies (Tables)

9 Months Ended

Sep. 30, 2021

Commitments and Contingencies Disclosure [Abstract]

Summary of Total Guarantees

A summary, by type and term, of amounts guaranteed by Con Edison and its subsidiaries under these agreements at September 30, 2021 is as follows:

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years	Total
	(Millions of Dollars)
Con Edison Transmission	$547	$—	$—	$547
Energy transactions	475	33	323	831
Renewable electric production projects	320	64	378	762
Other	70	—	—	70
Total	$1,412	$97	$701	$2,210

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Leases (Tables)

9 Months Ended

Sep. 30, 2021

Leases [Abstract]

Lease Costs, Cash Flows and Other Related Information

Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Operating lease cost	$22	$21	$16	$16
Operating lease cash flows	$10	$10	$6	$6

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Operating lease cost	$65	$63	$49	$48
Operating lease cash flows	$26	$27	$15	$13

Other information related to leases for Con Edison and CECONY at September 30, 2021 and December 31, 2020 were as follows:

	Con Edison		CECONY
	2021	2020	2021	2020
Weighted Average Remaining Lease Term:
Operating leases	18.5 years	19.1 years	12.4 years	13.0 years
Finance leases	7.1 years	7.3 years	3.3 years	4.0 years
Weighted Average Discount Rate:
Operating leases	4.3%	4.3%	3.6%	3.6%
Finance leases	1.8%	1.8%	1.2%	1.3%

Operating Leases, Future Minimum Lease Payments

Future minimum lease payments under non-cancellable leases at September 30, 2021 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending September 30,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2022	$82	$1	$59	$1
2023	76	—	58	—
2024	75	—	57	—
2025	76	—	58	—
2026	75	—	58	—
All years thereafter	937	1	446	—
Total future minimum lease payments	$1,321	$2	$736	$1
Less: imputed interest	(452)	—	(144)	—
Total	$869	$2	$592	$1
Reported as of September 30, 2021
Operating lease liabilities (current)	$113	$—	$85	$—
Operating lease liabilities (noncurrent)	756	—	507	—
Other current liabilities	—	1	—	—
Other noncurrent liabilities	—	1	—	1
Total	$869	$2	$592	$1

Finance Leases, Future Minimum Lease Payments

Future minimum lease payments under non-cancellable leases at September 30, 2021 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending September 30,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2022	$82	$1	$59	$1
2023	76	—	58	—
2024	75	—	57	—
2025	76	—	58	—
2026	75	—	58	—
All years thereafter	937	1	446	—
Total future minimum lease payments	$1,321	$2	$736	$1
Less: imputed interest	(452)	—	(144)	—
Total	$869	$2	$592	$1
Reported as of September 30, 2021
Operating lease liabilities (current)	$113	$—	$85	$—
Operating lease liabilities (noncurrent)	756	—	507	—
Other current liabilities	—	1	—	—
Other noncurrent liabilities	—	1	—	1
Total	$869	$2	$592	$1

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Income Tax (Tables)

9 Months Ended

Sep. 30, 2021

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 September 30, 2021 and 2020 is as follows:

	Con Edison				CECONY
(% of Pre-tax income)	2021		2020		2021		2020
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income tax, net of federal income tax benefit	5		6		5		5
Amortization of excess deferred federal income taxes	(7)		(7)		(8)		(8)
Taxes attributable to non-controlling interests	4		(1)		—		—
Cost of removal	1		1		1		2
Other plant-related items	(1)		(1)		(1)		(1)
Renewable energy credits	(1)		(1)		—		—
Injuries and damages reserve	—		—		1		—
Prior period federal income tax return adjustments	(1)		—		(1)		—
Other	—		1		—		—
Effective tax rate	21	%	19	%	18	%	19	%

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 nine months ended September 30, 2021 and 2020 is as follows:

	Con Edison				CECONY
(% of Pre-tax income)	2021		2020		2021		2020
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income tax, net of federal income tax benefit	5		5		5		5
Amortization of excess deferred federal income taxes	(11)		(10)		(11)		(10)
Taxes attributable to non-controlling interests	3		(1)		—		—
Cost of removal	2		2		2		2
Other plant-related items	(1)		(1)		(1)		(2)
Renewable energy credits	(2)		(2)		—		—
Other	(1)		—		—		1
Effective tax rate	16	%	14	%	16	%	17	%

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Revenue Recognition (Tables)

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following table presents, for the three and nine months ended September 30, 2021 and 2020, revenue from contracts with customers as defined in Accounting Standards Codification 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 September 30, 2021			For the Three Months Ended September 30, 2020
(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	$2,776	$(46)	$2,730	$2,594	$(32)	$2,562
Gas	305	2	307	248	11	259
Steam	52	3	55	50	1	51
Total CECONY	$3,133	$(41)	$3,092	$2,892	$(20)	$2,872
O&R
Electric	229	(6)	223	210	(2)	208
Gas	32	2	34	27	3	30
Total O&R	$261	$(4)	$257	$237	$1	$238
Clean Energy Businesses
Renewables	199	—	199	194	—	194
Energy services	65	—	65	14	—	14
Other	—	—	—	—	14	14
Total Clean Energy Businesses	$264	$0	$264	$208	$14	$222
Con Edison Transmission	1	—	1	1	—	1
Other (b)	—	(1)	(1)	—	—	—
Total Con Edison	$3,659	$(46)	$3,613	$3,338	$(5)	$3,333

(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)    Parent company and consolidation adjustments.

	For the Nine Months Ended September 30, 2021			For the Nine Months Ended September 30, 2020
(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	$6,695	$(34)	$6,661	$6,108	$70	$6,178
Gas	1,699	31	1,730	1,480	29	1,509
Steam	383	10	393	375	10	385
Total CECONY	$8,777	$7	$8,784	$7,963	$109	$8,072
O&R
Electric	535	(13)	522	478	5	483
Gas	184	(7)	177	156	8	164
Total O&R	$719	$(20)	$699	$634	$13	$647
Clean Energy Businesses
Renewables	545	—	545	487	—	487
Energy services	168	—	168	36	—	36
Other	—	66	66	—	43	43
Total Clean Energy Businesses	$713	$66	$779	$523	$43	$566
Con Edison Transmission	3	—	3	3	—	3
Other (b)	—	(4)	(4)	—	(2)	(2)
Total Con Edison	$10,212	$49	$10,261	$9,123	$163	$9,286

(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)    Parent company and consolidation adjustments.

Change in Unbilled Contract and Unearned Revenues

	2021			2020
(Millions of Dollars)	Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)
Beginning balance as of January 1,	$11	$41		$29	$17
Additions (c)	174	—		74	31
Subtractions (c)	127	31	(d)	90	4	(d)
Ending balance as of September 30,	$58	$10		$13	$44

(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, $31 million and $4 million were included in the balances as of January 1, 2021 and 2020, respectively.

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Current Expected Credit Losses (Tables)

9 Months Ended

Sep. 30, 2021

Credit Loss [Abstract]

Rollforward of Allowance for Credit Losses

The table below presents a rollforward by major portfolio segment type for the three and nine months ended September 30, 2021 and 2020:

	For the Three Months Ended September 30,
	Con Edison				CECONY
	Accounts receivable - customers		Other receivables		Accounts receivable - customers		Other receivables
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
Allowance for credit losses
Beginning Balance at July 1,	$275	$87	$7	$5	$262	$81	$4	$3
Recoveries	3	2	—	—	3	2	—	—
Write-offs	(24)	(4)	—	—	(23)	(3)	—	—
Reserve adjustments	59	33	—	1	58	31	1	1
Ending Balance September 30,	$313	$118	$7	$6	$300	$111	$5	$4

	For the Nine Months Ended September 30,
	Con Edison				CECONY
	Accounts receivable - customers		Other receivables		Accounts receivable - customers		Other receivables
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
Allowance for credit losses
Beginning Balance at January 1,	$148	$70	$7	$4	$138	$65	$4	$3
Recoveries	9	6	—	—	8	6	—	—
Write-offs	(66)	(37)	(1)	(1)	(62)	(35)	—	—
Reserve adjustments	222	79	1	3	216	75	1	1
Ending Balance September 30,	$313	$118	$7	$6	$300	$111	$5	$4

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Financial Information by Business Segment (Tables)

9 Months Ended

Sep. 30, 2021

Segment Reporting [Abstract]

Financial Data for Business Segments

The financial data for the business segments for the three and nine months ended September 30, 2021 and 2020 were as follows:

	For the Three Months Ended September 30,
	Operating revenues		Inter-segment revenues		Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
CECONY
Electric	$2,730	$2,562	$5	$4	$324	$305	$834	$813
Gas	307	259	2	2	82	74	(48)	(34)
Steam	55	51	18	18	23	22	(58)	(57)
Consolidation adjustments	—	—	(25)	(24)	—	—	—	—
Total CECONY	$3,092	$2,872	$—	$—	$429	$401	$728	$722
O&R
Electric	$223	$208	$—	$—	$18	$17	$55	$58
Gas	34	30	—	—	6	6	(8)	(9)
Total O&R	$257	$238	$—	$—	$24	$23	$47	$49
Clean Energy Businesses	$264	$222	$—	$—	$58	$58	$79	$92
Con Edison Transmission	1	1	—	—	—	—	(2)	(2)
Other (a)	(1)	—	—	—	1	—	(2)	(1)
Total Con Edison	$3,613	$3,333	$—	$—	$512	$482	$850	$860

(a) Parent company and consolidation adjustments. Other does not represent a business segment.

	For the Nine Months Ended September 30,
	Operating revenues		Inter-segment revenues		Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2021	2020	2021	2020	2021	2020	2021	2020
CECONY
Electric	$6,661	$6,178	$14	$13	$959	$904	$1,337	$1,413
Gas	1,730	1,509	6	5	239	216	490	440
Steam	393	385	55	56	69	67	9	1
Consolidation adjustments	—	—	(75)	(74)	—	—	—	—
Total CECONY	$8,784	$8,072	$—	$—	$1,267	$1,187	$1,836	$1,854
O&R
Electric	$522	$483	$—	$—	$52	$48	$78	$86
Gas	177	164	—	—	19	19	30	28
Total O&R	$699	$647	$—	$—	$71	$67	$108	$114
Clean Energy Businesses	$779	$566	$—	$—	$172	$173	$196	$188
Con Edison Transmission	3	3	—	—	1	1	(7)	(6)
Other (a)	(4)	(2)	—	—	—	—	(4)	(3)
Total Con Edison	$10,261	$9,286	$—	$—	$1,511	$1,428	$2,129	$2,147

(a) Parent company and consolidation adjustments. Other does not represent a business segment.

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Derivative Instruments and Hedging Activities (Tables)

9 Months Ended

Sep. 30, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Offsetting of Liabilities

The fair values of the Companies’ derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at September 30, 2021 and December 31, 2020 were:

(Millions of Dollars)	2021				2020
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	$652	$(375)	$277	(b)	$44	$14	$58	(b)
Noncurrent	140	(15)	125	(c)	22	35	57
Total fair value of derivative assets	$792	$(390)	$402		$66	$49	$115
Fair value of derivative liabilities
Current	$(428)	$265	$(163)	(c)	$(225)	$(13)	$(238)	(d)
Noncurrent	(183)	17	(166)	(c)	(207)	(33)	(240)	(d)
Total fair value of derivative liabilities	$(611)	$282	$(329)		$(432)	$(46)	$(478)
Net fair value derivative assets/(liabilities)	$181	($108)	$73		$(366)	$3	$(363)
CECONY
Fair value of derivative assets
Current	$407	$(183)	$224	(b)	$20	$(12)	$8	(b)
Noncurrent	114	(28)	86		16	(8)	8
Total fair value of derivative assets	$521	$(211)	$310		$36	$(20)	$16
Fair value of derivative liabilities
Current	$(158)	$44	$(114)		$(174)	$11	$(163)
Noncurrent	(125)	28	(97)		(114)	9	(105)
Total fair value of derivative liabilities	$(283)	$72	$(211)		$(288)	$20	$(268)
Net fair value derivative assets/(liabilities)	$238	$(139)	$99		$(252)	$—	$(252)

(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 September 30, 2021, immaterial amounts of margin deposits for Con Edison and CECONY were classified as derivative assets on the consolidated balance sheet, but not included in the table. At December 31, 2020, margin deposits for Con Edison and CECONY of $3 million 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)Includes amounts for interest rate swaps of $5 million in noncurrent assets, $(26) million in current liabilities and $(39) million in noncurrent liabilities. At September 30, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,046 million. The expiration dates of the swaps range from 2025-2041. In June 2021, as part of the Clean Energy Businesses' sale of a renewable electric project, interest rate swaps terminating in 2024 were assumed by the buyer.

(d)Includes amounts for interest rate swaps of $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps ranged from 2024-2041.

Offsetting of Assets

The fair values of the Companies’ derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at September 30, 2021 and December 31, 2020 were:

(Millions of Dollars)	2021				2020
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	$652	$(375)	$277	(b)	$44	$14	$58	(b)
Noncurrent	140	(15)	125	(c)	22	35	57
Total fair value of derivative assets	$792	$(390)	$402		$66	$49	$115
Fair value of derivative liabilities
Current	$(428)	$265	$(163)	(c)	$(225)	$(13)	$(238)	(d)
Noncurrent	(183)	17	(166)	(c)	(207)	(33)	(240)	(d)
Total fair value of derivative liabilities	$(611)	$282	$(329)		$(432)	$(46)	$(478)
Net fair value derivative assets/(liabilities)	$181	($108)	$73		$(366)	$3	$(363)
CECONY
Fair value of derivative assets
Current	$407	$(183)	$224	(b)	$20	$(12)	$8	(b)
Noncurrent	114	(28)	86		16	(8)	8
Total fair value of derivative assets	$521	$(211)	$310		$36	$(20)	$16
Fair value of derivative liabilities
Current	$(158)	$44	$(114)		$(174)	$11	$(163)
Noncurrent	(125)	28	(97)		(114)	9	(105)
Total fair value of derivative liabilities	$(283)	$72	$(211)		$(288)	$20	$(268)
Net fair value derivative assets/(liabilities)	$238	$(139)	$99		$(252)	$—	$(252)

(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 September 30, 2021, immaterial amounts of margin deposits for Con Edison and CECONY were classified as derivative assets on the consolidated balance sheet, but not included in the table. At December 31, 2020, margin deposits for Con Edison and CECONY of $3 million 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)Includes amounts for interest rate swaps of $5 million in noncurrent assets, $(26) million in current liabilities and $(39) million in noncurrent liabilities. At September 30, 2021, the Clean Energy Businesses had interest rate swaps with notional amounts of $1,046 million. The expiration dates of the swaps range from 2025-2041. In June 2021, as part of the Clean Energy Businesses' sale of a renewable electric project, interest rate swaps terminating in 2024 were assumed by the buyer.

(d)Includes amounts for interest rate swaps of $(24) million in current liabilities and $(82) million in noncurrent liabilities. At December 31, 2020, the Clean Energy Businesses had interest rate swaps with notional amounts of $863 million. The expiration dates of the swaps ranged from 2024-2041.

Realized and Unrealized Gains or Losses on Commodity Derivatives

The following table presents the realized and unrealized gains or losses on derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, 2021 and 2020:

		For the Three Months Ended September 30,
		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2021	2020	2021	2020
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$296	$26	$279	$24
Noncurrent	Deferred derivative gains	70	17	66	16
Total deferred gains/(losses)		$366	$43	$345	$40
Current	Deferred derivative losses	$(4)	$(9)	$(3)	$(11)
Current	Recoverable energy costs	17	(23)	13	(19)
Noncurrent	Deferred derivative losses	(61)	(15)	(55)	(12)
Total deferred gains/(losses)		($48)	$(47)	$(45)	$(42)
Net deferred gains/(losses)		$318	$(4)	$300	$(2)
	Income Statement Location
Pre-tax gains/(losses) recognized in income
	Gas purchased for resale	$2	$—	$—	$—
	Non-utility revenue	(23)	(2)	—	—
	Other operations and maintenance expense	1	—	1	—
	Other interest expense	11	7	—	—
Total pre-tax gains/(losses) recognized in income		$(9)	$5	$1	$—

		For the Nine Months Ended September 30,
		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2021	2020	2021	2020
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$443	$23	$415	$20
Noncurrent	Deferred derivative gains	106	15	97	14
Total deferred gains/(losses)		$549	$38	$512	$34
Current	Deferred derivative losses	$25	$12	$22	$9
Current	Recoverable energy costs	(30)	(163)	(29)	(144)
Noncurrent	Deferred derivative losses	(16)	(73)	(13)	(70)
Total deferred gains/(losses)		$(21)	$(224)	$(20)	$(205)
Net deferred gains/(losses)		$528	$(186)	$492	$(171)
	Income Statement Location
Pre-tax gains/(losses) recognized in income
	Gas purchased for resale	$4	$(3)	$—	$—
	Non-utility revenue	(22)	3	—	—
	Other operations and maintenance expense	5	(5)	5	(5)
	Other interest expense	45	(82)	—	—
Total pre-tax gains/(losses) recognized in income		$32	$(87)	$5	$(5)

Hedged Volume of Derivative Transactions

The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at September 30, 2021:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	23,870,400	39,914	280,838,997	4,704,000
CECONY	21,401,150	29,700	261,010,000	4,704,000

(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 September 30, 2021:

(Millions of Dollars)	Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$211		$176
Collateral posted	170		165
Additional collateral (b) (downgrade one level from current ratings)	24		4
Additional collateral (b) (downgrade to below investment grade from current ratings)	83	(c)	54	(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 $14 million of additional collateral at September 30, 2021. 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 September 30, 2021, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $72 million.

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Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2021

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 September 30, 2021 and December 31, 2020 are summarized below.

	2021					2020
(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)	$215	$533	$29	$(380)	$397	$19	$42	$4	$53	$118
Interest rate swaps (a)(b)(c)	—	5	—	—	5	—	—	—	—	—
Other (a)(b)(d)	479	136	—	—	615	431	126	—	—	557
Total assets	$694	$674	$29	$(380)	$1,017	$450	$168	$4	$53	$675
Derivative liabilities:
Commodity (a)(b)(c)	$40	$462	$34	$(272)	$264	$7	$296	$23	$46	$372
Interest rate swaps (a)(b)(c)	—	65	—	—	65	—	106	—	—	106
Total liabilities	$40	$527	$34	$(272)	$329	$7	$402	$23	$46	$478
CECONY
Derivative assets:
Commodity (a)(b)(c)	$142	$367	$2	$(201)	$310	$15	$20	$—	$(16)	$19
Other (a)(b)(d)	460	128	—	—	588	411	120	—	—	531
Total assets	$602	$495	$2	$(201)	$898	$426	$140	$—	$(16)	$550
Derivative liabilities:
Commodity (a)(b)(c)	$—	$253	$19	$(61)	$211	$3	$274	$10	$(19)	$268

(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 nine months ended September 30, 2021. Con Edison and CECONY had $1 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2020 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2020 to less than three years as of December 31, 2020.

(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, and 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 September 30, 2021 and December 31, 2020, 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.

Schedule of Commodity Derivatives

	Fair Value of Level 3 at September 30, 2021	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)
Con Edison – Commodity
Electricity	$11	Discounted Cash Flow	Forward energy prices (a)	$15.00-$130.75 per MWh
	(17)	Discounted Cash Flow	Forward capacity prices (a)	$0.26-$12.93 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(4.21)-$10.11 per MWh
Total Con Edison—Commodity	$(5)
CECONY – Commodity
Electricity	$(9)	Discounted Cash Flow	Forward energy prices (a)	$26.80-$98.51 per MWh
	(10)	Discounted Cash Flow	Forward capacity prices (a)	$0.70-$12.93 per kW-month
Transmission Congestion Contracts	2	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.63-$5.63 per MWh
Total CECONY—Commodity	$(17)

(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 September 30, 2021 and 2020 and classified as Level 3 in the fair value hierarchy:

	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance as of July 1,	$(9)	$(14)	$(7)	$(7)
Included in earnings	21	—	1	—
Included in regulatory assets and liabilities	(17)	(3)	(11)	(1)
Settlements	—	—	—	(1)
Ending balance as of September 30,	$(5)	$(17)	$(17)	$(9)

	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2021	2020	2021	2020
Beginning balance as of January 1,	$(19)	$(16)	$(10)	$(6)
Included in earnings	20	(7)	(2)	(3)
Included in regulatory assets and liabilities	(9)	(3)	(7)	(3)
Settlements	3	9	2	3
Ending balance as of September 30,	$(5)	$(17)	$(17)	$(9)

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Variable Interest Entities (Tables)

9 Months Ended

Sep. 30, 2021

Equity Method Investments and Joint Ventures [Abstract]

Summary of VIEs

At September 30, 2021 and December 31, 2020, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs:

	Tax Equity Projects
	Great Valley Solar (c)(d)		Copper Mountain - Mesquite Solar  (c)(e)		CED Nevada Virginia (c)(h)
(Millions of Dollars)	2021	2020	2021	2020	2021
Non-utility property, less accumulated depreciation (f)(g)	$278	$284	$435	$446	$647
Other assets	40	39	174	176	57
Total assets (a)	$318	$323	$609	$622	$704
Other liabilities	14	13	79	71	328
Total liabilities (b)	$14	$13	$79	$71	$328

(a)The assets of the Tax Equity Projects and CED Nevada Virginia 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 CED Nevada Virginia 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 $88 million and $82 million at September 30, 2021 and December 31, 2020, 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 $122 million and $134 million at September 30, 2021 and December 31, 2020, respectively.

(f)Non-utility property is reduced by accumulated depreciation of $24 million for Great Valley Solar, $40 million for Copper Mountain - Mesquite Solar, and $5 million for CED Nevada Virginia at September 30, 2021.

(g)Non-utility property is reduced by accumulated depreciation of $18 million for Great Valley Solar and $30 million for Copper Mountain - Mesquite Solar at December 31, 2020.

(h)CED Nevada Virginia consists of the Copper Mountain Solar 5, Battle Mountain Solar and Water Strider Solar projects for which the noncontrolling interest of the tax equity investor was $128 million at September 30, 2021.

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General (Details)	9 Months Ended
	Sep. 30, 2021 registrant subsidiary
Accounting Policies [Abstract]
Number of registrants | registrant	2
Number of regulated utility subsidiaries | subsidiary	2

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Summary of Significant Accounting Policies and Other Matters - Investments (Details) - Stagecoach Gas Services LLC - USD ($) $ in Millions	1 Months Ended		3 Months Ended	9 Months Ended
	Jul. 31, 2021	May 31, 2021	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021
Schedule of Equity Method Investments [Line Items]
Loss on sale of investment (pre-tax)				$ 211.0
Loss on sale of investment				147.0
Equity method investments					$ 630.0	$ 667.0
Con Edison Transmission | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Proceeds from sale	$ 1,195.0	$ 1,225.0
Ownership percentage		50.00%
Impairment charge				$ 414.0
Con Edison Transmission | Scenario, Forecast | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Proceeds from sale			$ 30.0
CET Gas | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Proceeds from sale	$ 614.0	$ 612.5
CET Gas | Scenario, Forecast | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Proceeds from sale			$ 15.0

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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		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Accounting Policies [Abstract]
Net income for common stock	$ 538	$ 493	$ 1,122	$ 1,058
Weighted average common shares outstanding – basic (shares)	353.4	334.5	346.8	334.1
Add: Incremental shares attributable to effect of potentially dilutive securities (shares)	0.7	0.9	0.7	0.9
Adjusted weighted average common shares outstanding – diluted (shares)	354.1	335.4	347.5	335.0
Net income per common share - basic (dollars per share)	$ 1.52	$ 1.47	$ 3.23	$ 3.17
Net income per common share - diluted (dollars per share)	$ 1.52	$ 1.47	$ 3.23	$ 3.16

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Summary of Significant Accounting Policies and Other Matters - Changes in Accumulated Other Comprehensive Income/(Loss) (Details) - USD ($) $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2021	Sep. 30, 2020
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	$ 20,053	$ 19,282	$ 19,065	$ 18,441	$ 18,467	$ 18,213	$ 19,065	$ 18,213
Beginning Balance			18,847				18,847
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	2	2	4	2		5	8	7
Ending Balance	20,377	20,053	19,282	18,711	18,441	18,467	20,377	18,711
Ending Balance	20,037						20,037
Subsidiaries
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	15,924	15,192	14,849	14,265	14,333	14,147	14,849	14,147
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES					1	1
Ending Balance	16,220	15,924	15,192		14,265	14,333	16,220
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(19)		(25)	(14)		(19)	(25)	(19)
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES				2
Ending Balance	(17)	(19)		(12)	(14)		(17)	(12)
Pension Plan LIabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax							2	4
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	2			2			6	3
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	2			2			8	7
OCI before reclassifications, tax							(1)
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(1)			(1)			(1)	(1)
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(19)	(21)	(25)		(14)	(19)	(25)	(19)
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	2	2	4			5
Ending Balance	(17)	(19)	(21)			(14)	(17)
Accumulated OCI | Subsidiaries
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning Balance	(7)	(7)	(7)	(4)	(5)	(6)	(7)	(6)
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES					1	1
Ending Balance	(7)	$ (7)	$ (7)	(4)	$ (4)	$ (5)	(7)	(4)
Pension Plan Liabilities | Subsidiaries
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax							0	0
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	0			0			0	2
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	$ 0			0			0	2
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES				0
Ending Balance				14,575				14,575
CECONY | Pension Plan LIabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax							$ (2)
CECONY | Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES				0
Ending Balance				$ (4)				$ (4)

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Summary of Significant Accounting Policies and Other Matters - Reconciliation of Cash, Temporary Investments and Restricted Cash (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020	Sep. 30, 2020	Dec. 31, 2019
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	$ 66	$ 1,272	$ 153
Restricted cash	149		161
Total cash, temporary cash investments and restricted cash	215	1,436	314	$ 1,217
Subsidiaries
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	18	1,067	23
Restricted cash	0		0
Total cash, temporary cash investments and restricted cash	18	$ 1,067	23	$ 933
CEB | Cash Collateral Held for Project Finance Agreements
Cash and Cash Equivalents [Line Items]
Restricted cash	$ 149		$ 161

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Regulatory Matters - Rate Plans (Details) - USD ($) $ in Millions	1 Months Ended
	Oct. 31, 2021	Sep. 30, 2021	May 31, 2021
O&R | Electric and Gas Transmission Projects | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Rate proposal, period of rate plans	3 years
Recovery of late payment charges, period	3 years
Recovery of late payment charges, amount	$ 2.8
Recovery of late payment charges, return on equity threshold rate	0.05%
RECO | NJBPU | Electric | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount			$ 16.9
Return on common equity (percent)			1000.00%
Common equity ratio (percent)			4925.00%
RECO | NJBPU | Electric | Subsidiaries | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount	$ 19.5
Return on common equity (percent)	10.00%
Common equity ratio (percent)	4884.00%
RECO | NJBPU | Electric | Deferred storm costs | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ 3.7	$ 1.0

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Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Electric) (Details) - USD ($) $ in Millions	36 Months Ended
	Dec. 31, 2024	Sep. 30, 2021
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
O&R | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)	9.20%
Earnings sharing (percent)	9.70%
Common equity ratio (percent)	48.00%
Deferrals for property taxes limitation from rates (percent)	90.00%
O&R | Electric | Scenario, Forecast | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes	$ 4.9
Amortization to income of net regulatory assets	11.8
Potential earnings adjustment mechanism incentives	3.3
Net utility plant reconciliations	1,175.0
Average rate base	$ 1,021.0
Weighted average cost of capital (after-tax) (percent)	6.77%
Cost of long-term debt (percent)	4.58%
Requested rate increase (decrease), amount	$ 11.7
Regulatory Asset, Amortization Period	5 years
Deferral, annual maximum (not more than) (percent)	0.10%
O&R | Electric | Scenario, Forecast | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)	$ 4.3
O&R | Electric | Scenario, Forecast | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes	16.2
Amortization to income of net regulatory assets	13.5
Potential earnings adjustment mechanism incentives	2.3
Net utility plant reconciliations	1,198.0
Average rate base	$ 1,044.0
Weighted average cost of capital (after-tax) (percent)	6.73%
Cost of long-term debt (percent)	4.51%
Requested rate increase (decrease), amount	$ 11.7
Deferral, annual maximum (not more than) (percent)	0.075%
O&R | Electric | Scenario, Forecast | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)	$ 4.4
O&R | Electric | Scenario, Forecast | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes	23.1
Amortization to income of net regulatory assets	15.2
Potential earnings adjustment mechanism incentives	4.0
Net utility plant reconciliations	1,304.0
Average rate base	$ 1,144.0
Weighted average cost of capital (after-tax) (percent)	6.72%
Cost of long-term debt (percent)	4.49%
Requested rate increase (decrease), amount	$ 11.7
Deferral, annual maximum (not more than) (percent)	0.05%
O&R | Electric | Scenario, Forecast | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)	$ 5.1

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Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Gas) (Details) - USD ($) $ in Millions	36 Months Ended
	Dec. 31, 2024	Sep. 30, 2021
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)	9.20%
Earnings sharing (percent)	9.70%
Common equity ratio (percent)	48.00%
Deferrals for property taxes limitation from rates (percent)	90.00%
O&R | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes	$ 0.7
Amortization to income of net regulatory assets	0.8
Potential earnings adjustment mechanism incentives	0.2
Potential Positive Rate Adjustment Gas Safety And Performance Revenue	1.2
Net utility plant reconciliations	720.0
Average rate base	$ 566.0
Weighted average cost of capital (after-tax) (percent)	6.77%
Cost of long-term debt (percent)	4.58%
Requested rate increase (decrease), amount	$ 4.4
Deferral, annual maximum (not more than) (percent)	0.10%
O&R | Gas | Year 1 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)	$ 6.3
O&R | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes	7.4
Amortization to income of net regulatory assets	0.7
Potential earnings adjustment mechanism incentives	0.2
Potential Positive Rate Adjustment Gas Safety And Performance Revenue	1.3
Net utility plant reconciliations	761.0
Average rate base	$ 607.0
Weighted average cost of capital (after-tax) (percent)	6.73%
Cost of long-term debt (percent)	4.51%
Requested rate increase (decrease), amount	$ 4.4
Deferral, annual maximum (not more than) (percent)	0.075%
O&R | Gas | Year 2 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)	$ 6.7
O&R | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes	9.9
Amortization to income of net regulatory assets	0.3
Potential earnings adjustment mechanism incentives	0.4
Potential Positive Rate Adjustment Gas Safety And Performance Revenue	1.4
Net utility plant reconciliations	803.0
Average rate base	$ 649.0
Weighted average cost of capital (after-tax) (percent)	6.72%
Cost of long-term debt (percent)	4.49%
Requested rate increase (decrease), amount	$ 4.4
Deferral, annual maximum (not more than) (percent)	0.05%
O&R | Gas | Year 3 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)	$ 7.3

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Regulatory Matters - COVID-19 Regulatory Matters (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		4 Months Ended	9 Months Ended
	Apr. 30, 2021	Sep. 30, 2021	Sep. 30, 2020	Jun. 30, 2021	Sep. 30, 2021	Sep. 30, 2020	Jan. 01, 2021	Dec. 31, 2020
Public Utilities, General Disclosures [Line Items]
Reserve adjustments					$ 165.0	$ 48.0
Subsidiaries
Public Utilities, General Disclosures [Line Items]
Reserve adjustments					162.0	45.0
COVID-19
Public Utilities, General Disclosures [Line Items]
Deferred costs		$ 0.9			0.9
COVID-19 | CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Estimated forgone revenues		11.0	$ 17.0		46.0	36.0
COVID-19 | CECONY | Electric and Gas Transmission Projects | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Reserve adjustments					235.0
Write off				$ 12.0
COVID-19 | O&R | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Estimated forgone revenues		$ 1.0	$ 1.0		$ 3.0	$ 2.0
Late payment charges and fees	$ 52.0
Late payment charges and fees, surcharge recovery period					12 months
COVID-19 | O&R | Gas | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Reserve adjustments					$ 7.0
Write off				$ 2.0
Residential Customers | COVID-19 | CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Deferred revenue								$ 54.9
Summer Cooling Credit Program | Residential Customers | COVID-19 | CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Expected deferred revenue							$ 63.4
Cost of the program, recovery period					5 years

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Regulatory Matters - Other Regulatory Matters (Details) customer in Thousands, $ in Millions		1 Months Ended				3 Months Ended	6 Months Ended	9 Months Ended		12 Months Ended		36 Months Ended
	Jan. 01, 2022 USD ($)	Jul. 31, 2021 USD ($)	Nov. 30, 2020 USD ($) claim	Aug. 31, 2020 customer	Jul. 31, 2019 USD ($) customer	Mar. 31, 2019 USD ($)	Jun. 30, 2020 USD ($)	Sep. 30, 2021 USD ($)	Sep. 30, 2020	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2022 USD ($)
Public Utilities, General Disclosures [Line Items]
Other Customer-Provided Capital rate								1.80%	2.65%
Return on regulatory assets								$ 2,027.0		$ 1,696.0
Recovery period for deferred derivative losses								3 years
CECONY
Public Utilities, General Disclosures [Line Items]
Net regulatory assets								$ 1,180.0		1,200.0
CECONY | Commodity
Public Utilities, General Disclosures [Line Items]
Recovery period								4 years
CECONY | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Return on regulatory assets								$ 1,817.0		1,509.0
CECONY | NYSPSC | Manhattan Steam Main Rupture | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Property damage, clean up and response expense							$ 17.0
Capital and retirement costs							9.0
Loss contingency accrual							$ 3.0
CECONY | NYSPSC | Steam | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA						$ 15.0
Impact in regulatory liability resulting from TCJA						$ 185.0
Tax credit, amortization period						3 years
CECONY | Electric | West Side of Manhattan | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer				190	72
Estimate of possible loss (up to)					$ 24.8
CECONY | Electric | Brooklyn
Public Utilities, General Disclosures [Line Items]
Revenues, negative adjustment											$ 15.0
CECONY | Electric | Brooklyn | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer					30
CECONY | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer				330
Settlement agreement, amount		$ 75.1
Estimate of possible loss (up to)			$ 102.3
Restoration costs								175.0
Operation and maintenance expenses charged against a storm reserve								84.0
Capital expenditures								64.0
Operation and maintenance expenses								27.0
Food and medicine spoilage expense								$ 7.5
Alleged number of claims, violations | claim			33
Litigation settlement, period								35 years
CECONY | Electric | Tropical Storm | Foregone Customer Recovery | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		25.0
CECONY | Electric | Tropical Storm | Ongoing Operations And Maintenance Costs | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		15.8
CECONY | Electric | Tropical Storm | Costs To Reimburse Customers For Food And Medicine Spoilage | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		14.3
CECONY | Electric | Tropical Storm | Previously Incurred Or Accrued Costs | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		34.3
CECONY | Electric | Rainey Outages | Negative Revenue Adjustment | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		5.0
CECONY | Electric | 2019 Manhattan and Brooklyn Outages | Negative Revenue Adjustment | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		15.0
CECONY | Electric | Scenario, Forecast | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA												$ 377.0
TCJA, net benefit amortization, allocation period												3 years
CECONY | Electric | Scenario, Forecast | Protected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Impact in regulatory liability resulting from TCJA												$ 1,663.0
CECONY | Electric | Scenario, Forecast | Unprotected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period												5 years
Impact in regulatory liability resulting from TCJA												$ 784.0
CECONY | Gas | Scenario, Forecast | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA												$ 63.0
TCJA, net benefit amortization, allocation period												2 years
CECONY | Gas | Scenario, Forecast | Protected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Impact in regulatory liability resulting from TCJA												$ 725.0
CECONY | Gas | Scenario, Forecast | Unprotected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period												5 years
Impact in regulatory liability resulting from TCJA												$ 107.0
O&R
Public Utilities, General Disclosures [Line Items]
Net regulatory assets								$ 26.0		29.0
O&R | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer				200
Settlement agreement, amount		7.0
Property damage, clean up and response expense								1.6
Estimate of possible loss (up to)			$ 19.0
Restoration costs								26.5
Operation and maintenance expenses charged against a storm reserve								19.2
Capital expenditures								5.7
Alleged number of claims, violations | claim			38
O&R | Electric | Tropical Storm | Foregone Customer Recovery | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		2.5
O&R | Electric | Tropical Storm | Ongoing Operations And Maintenance Costs | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		2.9
O&R | Electric | Tropical Storm | Previously Incurred Or Accrued Costs | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Settlement agreement, amount		$ 1.6
O&R | Electric and Gas Transmission Projects | Scenario, Forecast | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA												$ 22.0
TCJA, net benefit amortization, allocation period												3 years
O&R | Electric and Gas Transmission Projects | Scenario, Forecast | Protected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Impact in regulatory liability resulting from TCJA												$ 123.0
O&R | Electric and Gas Transmission Projects | Scenario, Forecast | Unprotected Portion | Subsidiaries
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period	6 years											15 years
Impact in regulatory liability resulting from TCJA	$ 34.0											$ 30.0
RECO | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Return on regulatory assets								24.0		$ 31.0
RECO | Electric | Tropical Storm | Subsidiaries
Public Utilities, General Disclosures [Line Items]
Restoration costs								11.3
Operation and maintenance expenses charged against a storm reserve								7.5
Capital expenditures								2.5
Food and medicine spoilage expense								$ 1.3

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Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	$ 5,903	$ 6,195
Regulatory assets – current	205	266
Total Regulatory Assets	6,108	6,461
Regulatory assets not earning return	4,081	4,766
Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	5,473	5,745
Regulatory assets – current	187	244
Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,527	3,241
Regulatory assets not earning return	2,527	3,241
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	846	865
Regulatory assets not earning return	832	855
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	438	315
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	385	356
Regulatory assets not earning return	364	336
Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	245	241
COVID-19 pandemic deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	274	115
Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	277	195
MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	152	188
System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	145	124
Deferred derivative losses - long term
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	136	120
Regulatory assets not earning return	136	120
Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	49	62
Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	35	36
Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	30	32
Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	20	21
Non-wire alternative projects
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	23	18
Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	17	21
Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	15	20
Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	15	25
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	274	200
Regulatory assets not earning return	56	24
Deferred derivative losses - short term
Regulatory Assets [Line Items]
Regulatory assets – current	166	190
Regulatory assets not earning return	166	190
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	39	76
CECONY | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	5,473	5,745
Regulatory assets – current	187	244
Total Regulatory Assets	5,660	5,989
Regulatory assets not earning return	3,843	4,481
CECONY | Unrecognized pension and other postretirement costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,394	3,065
Regulatory assets not earning return	2,394	3,065
CECONY | Environmental remediation costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	780	791
Regulatory assets not earning return	765	781
CECONY | Pension and other postretirement benefits deferrals | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	382	272
CECONY | Revenue taxes | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	369	342
Regulatory assets not earning return	349	323
CECONY | Property tax reconciliation | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	245	239
CECONY | COVID-19 pandemic deferrals | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	269	113
CECONY | Deferred storm costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	155	83
CECONY | MTA power reliability deferral | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	152	188
CECONY | System peak reduction and energy efficiency programs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	145	124
CECONY | Deferred derivative losses - long term | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	124	111
Regulatory assets not earning return	124	111
CECONY | Municipal infrastructure support costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	49	62
CECONY | Brooklyn Queens demand management program | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	35	36
CECONY | Meadowlands heater odorization project | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	30	32
CECONY | Preferred stock redemption | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	20	21
CECONY | Non-wire alternative projects | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	23	18
CECONY | Unamortized loss on reacquired debt | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	15	19
CECONY | Recoverable REV demonstration project costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	14	18
CECONY | Gate station upgrade project | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	15	25
CECONY | Other | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	257	186
Regulatory assets not earning return	56	24
CECONY | Deferred derivative losses - short term | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – current	155	177
Regulatory assets not earning return	155	177
CECONY | Recoverable energy costs | Subsidiaries
Regulatory Assets [Line Items]
Regulatory assets – current	$ 32	$ 67

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Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 4,379	$ 4,513
Regulatory liabilities – current	490	36
Total Regulatory Liabilities	4,869	4,549
Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	3,941	4,094
Regulatory liabilities – current	428	11
Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	2,040	2,207
Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,114	1,090
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	184	198
TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	167	295
Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	111	137
Deferred derivative gains - long term
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	110	5
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	98	85
System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	71	64
Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	17	1
Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	35	36
BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	26	27
Sales and use tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	18	16
Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	13	15
Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	12	11
Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	11	21
Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	6	5
Workers' compensation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5	3
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	341	297
Deferred derivative gains - short term
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	451	8
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	31	28
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	8	0
CECONY | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	3,941	4,094
Regulatory liabilities – current	428	11
Total Regulatory Liabilities	4,369	4,105
CECONY | Future income tax | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,896	2,062
CECONY | Allowance for cost of removal less salvage | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	950	932
CECONY | Net unbilled revenue deferrals | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	184	198
CECONY | TCJA net benefits | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	164	286
CECONY | Net proceeds from sale of property | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	111	137
CECONY | Deferred derivative gains - long term | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	101	4
CECONY | Pension and other postretirement benefit deferrals | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	53	46
CECONY | System benefit charge carrying charge | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	63	57
CECONY | Energy efficiency portfolio standard unencumbered funds | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	19	0
CECONY | Property tax refunds | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	35	35
CECONY | BQDM and REV Demo reconciliations | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	22	25
CECONY | Sales and use tax refunds | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	17	16
CECONY | Earnings sharing - electric, gas and steam | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	10
CECONY | Unrecognized other postretirement costs | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	0
CECONY | Settlement of gas proceedings | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	11	21
CECONY | Settlement of prudence proceeding | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	6	5
CECONY | Workers' compensation | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5	3
CECONY | Other | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	294	257
CECONY | Deferred derivative gains - short term | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	423	7
CECONY | Refundable energy costs | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	5	4
CECONY | Revenue decoupling mechanism | Subsidiaries
Regulatory Liabilities [Line Items]
Regulatory liabilities – current	$ 0	$ 0

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Capitalization - Additional Information (Details)	1 Months Ended		3 Months Ended
	Jun. 30, 2021 USD ($) shares	May 31, 2021 USD ($)	Sep. 30, 2021 USD ($)	Jun. 30, 2021 USD ($)	Mar. 31, 2021 USD ($)	Feb. 28, 2021 USD ($) project
Schedule of Capitalization [Line Items]
Issuance of common shares – public offering (shares) | shares	10,100,000
Proceeds from issuance of equity	$ 775,000,000
Borrowings Due 2028 | Clean Energy Businesses
Schedule of Capitalization [Line Items]
Face amount of debt						$ 250,000,000
Number of solar electric production projects | project						4
Interest rate						3.39%
Tax Equity Financing Agreement | Clean Energy Businesses
Schedule of Capitalization [Line Items]
Number of solar electric production projects | project						3
Amount funded from tax equity financing agreement			$ 263,000,000
2.40 percent maturing in 2031 | CECONY | Subsidiaries
Schedule of Capitalization [Line Items]
Face amount of debt			$ 750,000,000
Interest rate			2.40%
3.60 percent maturing in 2061 | CECONY | Subsidiaries
Schedule of Capitalization [Line Items]
Face amount of debt			$ 750,000,000
Interest rate			3.60%
2.00% Debentures Due 2021
Schedule of Capitalization [Line Items]
Interest rate		2.00%
Repayments of debt		$ 500,000,000
Debt instrument term		5 years
Floating Debentures | CECONY | Subsidiaries
Schedule of Capitalization [Line Items]
Repayments of debt	$ 640,000,000
Debt instrument term	3 years
Floating Rate Notes Due 2024 | Clean Energy Businesses
Schedule of Capitalization [Line Items]
Long-term debt			$ 37,000,000
2.31% Debenture Due 2031
Schedule of Capitalization [Line Items]
Face amount of debt			$ 45,000,000
Interest rate			231.00%
3.17% Debenture Due 2051
Schedule of Capitalization [Line Items]
Face amount of debt			$ 30,000,000
Interest rate			317.00%
Senior Notes | 3.77% Senior Notes Due 2046 | Clean Energy Businesses | Subsidiaries
Schedule of Capitalization [Line Items]
Face amount of debt	$ 229,000,000			$ 229,000,000	$ 3.77
Repayments of debt				$ 675,000,000
Senior Notes | 4.45% 10 Year Debentures | Clean Energy Businesses
Schedule of Capitalization [Line Items]
Interest rate			4.52%
Long-term debt			$ 104,000,000

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Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Debt Instrument [Line Items]
Unamortized debt expense	$ 221	$ 215
Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	22,280	22,349
Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	25,655	26,808
CECONY | Subsidiaries
Debt Instrument [Line Items]
Unamortized debt discount	188	176
CECONY | Carrying Amount | Subsidiaries
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	17,637	16,789
CECONY | Fair Value | Subsidiaries
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	$ 20,774	$ 20,974

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Short-Term Borrowing (Details) - USD ($)	1 Months Ended			9 Months Ended
	Aug. 31, 2021	Jul. 31, 2021	May 31, 2021	Sep. 30, 2021	Apr. 30, 2021	Dec. 31, 2020
Short-term Debt [Line Items]
Commercial paper, outstanding				$ 1,036,000,000		$ 1,705,000,000
Loans outstanding under the credit agreement				$ 0		0
Variable Rate Construction Loan Facility Maturing November 2021 | Clean Energy Businesses | Line of Credit
Short-term Debt [Line Items]
Repayments of lines of credit	$ 249,000,000
Line of credit terminated	$ 613,000,000
Banks' commitments under construction loan facility						613,000,000
Outstanding borrowings						$ 165,000,000
April 2021 Credit Agreement, Variable Rate 364 Day Term Loan | Line of Credit
Short-term Debt [Line Items]
Repayments of lines of credit		$ 500,000,000
Maximum borrowing capacity					$ 500,000,000
Debt instrument term				364 days
Proceeds from lines of credit			$ 500,000,000
2.00% Debentures Due 2021
Short-term Debt [Line Items]
Debt instrument term			5 years
Interest rate			2.00%
Commercial Paper
Short-term Debt [Line Items]
Weighted average interest rate				0.10%		0.30%
CECONY | Subsidiaries
Short-term Debt [Line Items]
Commercial paper, outstanding				$ 942,000,000		$ 1,660,000,000
CECONY | Commercial Paper | Subsidiaries
Short-term Debt [Line Items]
Weighted average interest rate				0.10%		0.30%

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Pension Benefits - Total Periodic Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 85	$ 73	$ 257	$ 220
Interest cost on projected benefit obligation	118	137	353	412
Expected return on plan assets	(274)	(258)	(822)	(775)
Recognition of net actuarial loss	197	175	590	524
Recognition of prior service credit	(4)	(4)	(12)	(12)
TOTAL PERIODIC BENEFIT COST	122	123	366	369
Cost capitalized	(41)	(34)	(120)	(98)
Reconciliation to rate level	(54)	(62)	(165)	(188)
Total credit recognized	27	27	81	83
CECONY | Subsidiaries
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	80	69	241	206
Interest cost on projected benefit obligation	111	129	332	387
Expected return on plan assets	(260)	(245)	(779)	(735)
Recognition of net actuarial loss	187	165	559	496
Recognition of prior service credit	(5)	(5)	(15)	(15)
TOTAL PERIODIC BENEFIT COST	113	113	338	339
Cost capitalized	(39)	(32)	(113)	(93)
Reconciliation to rate level	(52)	(59)	(158)	(179)
Total credit recognized	$ 22	$ 22	$ 67	$ 67

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Pension Benefits - Additional Information (Details) - Pension Benefits $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Estimated future employer contributions	$ 467
Contributions	465
CECONY | Subsidiaries
Defined Benefit Plan Disclosure [Line Items]
Estimated future employer contributions	429
Contributions	428
CECONY | Nonqualified Plan | Subsidiaries
Defined Benefit Plan Disclosure [Line Items]
Contributions	$ 22

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Other Postretirement Benefits - Periodic Postretirement Benefit Costs (Details) - Other Postretirement Benefits - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	$ 2	$ 5	$ 15	$ 16
Interest cost on projected other postretirement benefit obligation	7	9	23	28
Expected return on plan assets	(17)	(16)	(51)	(49)
Recognition of net actuarial loss/(gain)	4	3	17	34
Recognition of prior service credit	0	(1)	(2)	(3)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	(4)	0	2	26
Cost capitalized	(3)	(2)	(9)	(7)
Reconciliation to rate level	7	2	7	(19)
Total credit recognized	0	0	0	0
CECONY | Subsidiaries
Defined Benefit Plan Disclosure [Line Items]
Service cost - including administrative expenses	1	4	11	12
Interest cost on projected other postretirement benefit obligation	6	8	19	23
Expected return on plan assets	(14)	(14)	(41)	(41)
Recognition of net actuarial loss/(gain)	3	3	13	32
Recognition of prior service credit	0	0	(1)	(1)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	(4)	1	1	25
Cost capitalized	(3)	(2)	(7)	(5)
Reconciliation to rate level	6	0	2	(24)
Total credit recognized	$ (1)	$ (1)	$ (4)	$ (4)

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Other Postretirement Benefits - Additional Information (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($)
Other Postretirement Benefits | CECONY
Defined Benefit Plan Disclosure [Line Items]
Contributions	$ 2

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Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Site Contingency [Line Items]
Accrued liabilities	$ 841	$ 857
Regulatory assets	6,108	6,461
Subsidiaries
Site Contingency [Line Items]
Accrued liabilities	765	780
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued liabilities	737	752
Other Superfund Sites
Site Contingency [Line Items]
Accrued liabilities	104	105
Superfund Sites
Site Contingency [Line Items]
Accrued liabilities	841	857
Regulatory assets	846	865
CECONY | Subsidiaries
Site Contingency [Line Items]
Regulatory assets	5,660	5,989
CECONY | Manufactured gas plant sites | Subsidiaries
Site Contingency [Line Items]
Accrued liabilities	662	676
CECONY | Other Superfund Sites | Subsidiaries
Site Contingency [Line Items]
Accrued liabilities	103	104
CECONY | Superfund Sites | Subsidiaries
Site Contingency [Line Items]
Accrued liabilities	765	780
Regulatory assets	$ 780	$ 791

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Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 7	$ 8	$ 21	$ 17
CECONY | Subsidiaries
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 7	$ 8	$ 20	$ 16

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Environmental Matters - Additional Information (Details) - USD ($) $ in Billions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
CECONY | Asbestos Proceedings | Subsidiaries
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)		$ 2.7
Superfund Sites | Manufactured Gas Plant Sites | Maximum | CECONY | Subsidiaries
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)		$ 2.6

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Environmental Matters - Accrued Liability (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Site Contingency [Line Items]
Regulatory assets	$ 6,108	$ 6,461
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers’ Compensation
Site Contingency [Line Items]
Accrued liability	68	72
Regulatory assets	5	3
CECONY | Subsidiaries
Site Contingency [Line Items]
Regulatory assets	5,660	5,989
CECONY | Asbestos Suits | Subsidiaries
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY | Workers’ Compensation | Subsidiaries
Site Contingency [Line Items]
Accrued liability	65	68
Regulatory assets	$ 5	$ 3

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Other Material Contingencies - Manhattan Explosion and Fire (Details) $ in Millions		1 Months Ended
	Mar. 12, 2014 people building	Feb. 28, 2017 USD ($)	Sep. 30, 2021 USD ($) lawsuit	Dec. 31, 2020 USD ($)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 4,379	$ 4,513
Settlement of Gas Proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 11	21
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
Loss contingency accrual			$ 40	40
Insurance receivable			$ 40	$ 40
Manhattan Explosion and Fire | Settlement of Gas Proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability		$ 27

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Other Material Contingencies - Guarantees (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 2,210	$ 2,042
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	547
Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	831
Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	762
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	1,412
0 – 3 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	547
0 – 3 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	475
0 – 3 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	320
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	97
4 – 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	33
4 – 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	64
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	701
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	323
Greater than 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	378
Greater than 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 0

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Other Material Contingencies - Con Edison Transmission (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,210	$ 2,042
Stagecoach Gas Services LLC
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 7
Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Estimated project cost percentage	175.00%
NY Transco | Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Ownership interest, percentage	45.70%

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Other Material Contingencies - Other (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,210	$ 2,042
Financial Guarantee for Indemnity Agreements for Surety Bonds
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 70

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Leases - Lease Cost and Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 22	$ 21	$ 65	$ 63
Operating lease cash flows	10	10	26	27
CECONY | Subsidiaries
Lessee, Lease, Description [Line Items]
Operating lease cost	16	16	49	48
Operating lease cash flows	$ 6	$ 6	$ 15	$ 13

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Leases - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Assets under finance leases	$ 2		$ 2		$ 3
Finance leases, accumulated amortization	3		3		3
Right-of-use assets	15	$ 8	32	$ 13
CECONY | Subsidiaries
Lessee, Lease, Description [Line Items]
Assets under finance leases	1		1		2
Finance leases, accumulated amortization	2		2		$ 1
Right-of-use assets	$ 5	$ 2	$ 7	$ 3

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Leases - Other Related Information (Details)	Sep. 30, 2021	Dec. 31, 2020
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	18 years 6 months	19 years 1 month 6 days
Weighted Average Remaining Lease Term, Finance leases	7 years 1 month 6 days	7 years 3 months 18 days
Weighted Average Discount Rate, Operating leases	4.30%	4.30%
Weighted Average Discount Rate, Finance leases	1.80%	1.80%
CECONY | Subsidiaries
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	12 years 4 months 24 days	13 years
Weighted Average Remaining Lease Term, Finance leases	3 years 3 months 18 days	4 years
Weighted Average Discount Rate, Operating leases	3.60%	3.60%
Weighted Average Discount Rate, Finance leases	1.20%	1.30%

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Leases - Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Operating Leases
2022	$ 82
2023	76
2024	75
2025	76
2026	75
All years thereafter	937
Total future minimum lease payments	1,321
Less: imputed interest	(452)
Total	869
Operating lease liabilities (current)	113	$ 96
Operating lease liabilities (noncurrent)	756	764
Total	869
Finance Leases
2022	1
2023	0
2024	0
2025	0
2026	0
All years thereafter	1
Total future minimum lease payments	2
Less: imputed interest	0
Other current liabilities	1
Other noncurrent liabilities	1
Total	2
Subsidiaries
Operating Leases
Operating lease liabilities (current)	85	73
Operating lease liabilities (noncurrent)	507	$ 512
CECONY | Subsidiaries
Operating Leases
2022	59
2023	58
2024	57
2025	58
2026	58
All years thereafter	446
Total future minimum lease payments	736
Less: imputed interest	(144)
Total	592
Operating lease liabilities (current)	85
Operating lease liabilities (noncurrent)	507
Total	592
Finance Leases
2022	1
2023	0
2024	0
2025	0
2026	0
All years thereafter	0
Total future minimum lease payments	1
Less: imputed interest	0
Other current liabilities	0
Other noncurrent liabilities	1
Total	$ 1

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Income Tax - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Income Taxes Disclosure [Line Items]
Income tax expense (benefit)	$ 127.0	$ 119.0	$ 194.0	$ 183.0
Unprotected excess deferred federal income taxes amortization period			5 years
Estimated liability for uncertain tax positions	17.0		$ 17.0
Effective income tax rate reconciliation, uncertainty of taxes			3.0
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate	17.0		17.0
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate, net of federal taxes	16.0		16.0
Subsidiaries
Income Taxes Disclosure [Line Items]
Income tax expense (benefit)	90.0	97.0	188.0	$ 199.0
CECONY | Subsidiaries
Income Taxes Disclosure [Line Items]
Income tax expense (benefit)	90.0	$ 97.0
Estimated liability for uncertain tax positions	6.0		6.0
Effective income tax rate reconciliation, uncertainty of taxes			1.0
Total amount of unrecognized tax benefits, if recognized, that would reduce effective tax rate	$ 6.0		6.0
Tax Year 2013
Income Taxes Disclosure [Line Items]
Discrete income tax benefit			4.0
Tax Year 2018 to 2013
Income Taxes Disclosure [Line Items]
Operating loss carryback			$ 29.0
Net tax refund					$ 2.5

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Income Tax - Income Tax Reconciliation (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
STATUTORY TAX RATE
Federal	21.00%	21.00%	21.00%	21.00%
Changes in computed taxes resulting from:
State income tax, net of federal income tax benefit	5.00%	6.00%	5.00%	5.00%
Amortization of excess deferred federal income taxes	(7.00%)	(7.00%)	(11.00%)	(10.00%)
Taxes attributable to non-controlling interests	4.00%	(1.00%)	3.00%	(1.00%)
Cost of removal	1.00%	1.00%	2.00%	2.00%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)	(1.00%)
Renewable energy credits	(1.00%)	(1.00%)	(2.00%)	(2.00%)
Injuries and damages reserve	0.00%	0.00%
Prior period federal income tax return adjustments	(1.00%)	0.00%
Other	0.00%	1.00%	(1.00%)	0.00%
Effective tax rate	21.00%	19.00%	16.00%	14.00%
CECONY
Changes in computed taxes resulting from:
Prior period federal income tax return adjustments	(1.00%)	0.00%
CECONY | Subsidiaries
STATUTORY TAX RATE
Federal	21.00%	21.00%	21.00%	21.00%
Changes in computed taxes resulting from:
State income tax, net of federal income tax benefit	5.00%	5.00%	5.00%	5.00%
Amortization of excess deferred federal income taxes	(8.00%)	(8.00%)	(11.00%)	(10.00%)
Taxes attributable to non-controlling interests	0.00%	0.00%	0.00%	0.00%
Cost of removal	1.00%	2.00%	2.00%	2.00%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)	(2.00%)
Renewable energy credits	0.00%	0.00%	0.00%	0.00%
Injuries and damages reserve	1.00%	0.00%
Other	0.00%	0.00%	0.00%	1.00%
Effective tax rate	18.00%	19.00%	16.00%	17.00%

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Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 3,659	$ 3,338	$ 10,212	$ 9,123
Total revenues	3,613	3,333	10,261	9,286
Subsidiaries
Disaggregation of Revenue [Line Items]
Total revenues	3,092	2,872	8,784	8,072
Other
Disaggregation of Revenue [Line Items]
Total revenues	(46)	(5)	49	163
Operating Segments
Disaggregation of Revenue [Line Items]
Total revenues	3,613	3,333
Operating Segments | Electric
Disaggregation of Revenue [Line Items]
Total revenues			10,261	9,286
Operating Segments | Clean Energy Businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	264	208	713	523
Total revenues	264	222	779	566
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Total revenues	0	14	66	43
Operating Segments | Clean Energy Businesses | Renewables
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	199	194	545	487
Total revenues	199	194	545	487
Operating Segments | Clean Energy Businesses | Renewables | Other
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Operating Segments | Clean Energy Businesses | Energy services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	65	14	168	36
Total revenues	65	14	168	36
Operating Segments | Clean Energy Businesses | Energy services | Other
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Total revenues	0	14	66	43
Operating Segments | Clean Energy Businesses | Other | Other
Disaggregation of Revenue [Line Items]
Total revenues	0	14	66	43
Operating Segments | Con Edison Transmission
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1	1	3	3
Total revenues	1	1	3	3
Operating Segments | Con Edison Transmission | Other
Disaggregation of Revenue [Line Items]
Total revenues	0	0	0	0
Operating Segments | CECONY | Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	3,133	2,892	8,777	7,963
Total revenues	3,092	2,872	8,784	8,072
Operating Segments | CECONY | Other | Subsidiaries
Disaggregation of Revenue [Line Items]
Total revenues	(41)	(20)	7	109
Operating Segments | CECONY | Electric | Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,776	2,594	6,695	6,108
Total revenues	2,730	2,562	6,661	6,178
Operating Segments | CECONY | Electric | Other | Subsidiaries
Disaggregation of Revenue [Line Items]
Total revenues	(46)	(32)	(34)	70
Operating Segments | CECONY | Gas | Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	305	248	1,699	1,480
Total revenues	307	259	1,730	1,509
Operating Segments | CECONY | Gas | Other | Subsidiaries
Disaggregation of Revenue [Line Items]
Total revenues	2	11	31	29
Operating Segments | CECONY | Steam | Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	52	50	383	375
Total revenues	55	51	393	385
Operating Segments | CECONY | Steam | Other | Subsidiaries
Disaggregation of Revenue [Line Items]
Total revenues	3	1	10	10
Operating Segments | O&R | Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	261	237	719	634
Total revenues	257	238	699	647
Operating Segments | O&R | Other | Subsidiaries
Disaggregation of Revenue [Line Items]
Total revenues	(4)	1	(20)	13
Operating Segments | O&R | Electric | Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	229	210	535	478
Total revenues	223	208	522	483
Operating Segments | O&R | Electric | Other | Subsidiaries
Disaggregation of Revenue [Line Items]
Total revenues	(6)	(2)	(13)	5
Operating Segments | O&R | Gas | Subsidiaries
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	32	27	184	156
Total revenues	34	30	177	164
Operating Segments | O&R | Gas | Other | Subsidiaries
Disaggregation of Revenue [Line Items]
Total revenues	2	3	(7)	8
Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Total revenues	(1)	0	(4)	(2)
Other | Other
Disaggregation of Revenue [Line Items]
Total revenues	$ (1)	$ 0	(4)	$ (2)
Other | Con Edison Transmission
Disaggregation of Revenue [Line Items]
Total revenues			$ 3

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Revenue Recognition - Change in Unbilled Contract and Unearned Revenues (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Jan. 01, 2021	Jan. 01, 2020
Unbilled contract revenue
Beginning balance	$ 11	$ 29
Additions	174	74
Subtractions	127	90
Ending balance	58	13
Unearned revenue
Beginning balance	41	17
Additions	0	31
Subtractions	31	4
Ending balance	$ 10	$ 44
Contracts with customer, revenue recognized, amount outstanding end of last period			$ 31	$ 4

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Revenue Recognition - Revenue Recognition, Remaining Performance Obligation (Details) $ in Millions	Sep. 30, 2021 USD ($)
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 187
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 148
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]: 2023-01-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 39
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing of satisfaction

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Revenue Recognition - Additional information (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Apr. 30, 2021	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Late fee and other fees not collected		$ 12	$ 18	$ 49	$ 38
CECONY | Subsidiaries
Disaggregation of Revenue [Line Items]
Late fee and other fees not collected		$ 11	$ 17	$ 46	$ 36
O&R | COVID-19 | Subsidiaries
Disaggregation of Revenue [Line Items]
Late payment charges and fees	$ 52
Late payment charges and fees, surcharge recovery period				12 months

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Current Expected Credit Losses (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	$ 38	$ 31	$ 165	$ 48
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Reserve adjustments			165	48
Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Reserve adjustments			162	45
Accounts receivable - customers
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at July 1,	275	87	148	70
Recoveries	3	2	9	6
Write-offs	(24)	(4)	(66)	(37)
Reserve adjustments	59	33	222	79
Ending Balance September 30,	313	118	313	118
Other receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at July 1,	7	5	7	4
Recoveries	0	0	0	0
Write-offs	0	0	(1)	(1)
Reserve adjustments	0	1	1	3
Ending Balance September 30,	7	6	7	6
CECONY | Subsidiaries
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	38	30	162	46
CECONY | Accounts receivable - customers | Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at July 1,	262	81	138	65
Recoveries	3	2	8	6
Write-offs	(23)	(3)	(62)	(35)
Reserve adjustments	58	31	216	75
Ending Balance September 30,	300	111	300	111
CECONY | Other receivables | Subsidiaries
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance at July 1,	4	3	4	3
Recoveries	0	0	0	0
Write-offs	0	0	0	0
Reserve adjustments	1	1	1	1
Ending Balance September 30,	$ 5	$ 4	$ 5	$ 4

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Financial Information by Business Segment (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Segment Reporting Information [Line Items]
Total revenues	$ 3,613	$ 3,333	$ 10,261	$ 9,286
Depreciation and amortization	512	482	1,511	1,428
Operating income/(loss)	850	860	2,129	2,147
Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	3,092	2,872	8,784	8,072
Depreciation and amortization	429	401	1,267	1,187
Operating income/(loss)	728	722	1,836	1,854
Clean Energy Businesses
Segment Reporting Information [Line Items]
Depreciation and amortization	58	58	172	173
Operating income/(loss)	79	92	196	188
Con Edison Transmission
Segment Reporting Information [Line Items]
Depreciation and amortization	0	0	1	1
Operating income/(loss)	(2)	(2)	(7)	(6)
Electric
Segment Reporting Information [Line Items]
Depreciation and amortization			1,511	1,428
Operating income/(loss)			2,129	2,147
CECONY | Subsidiaries
Segment Reporting Information [Line Items]
Depreciation and amortization	429	401	1,267	1,187
Operating income/(loss)	728	722	1,836	1,854
CECONY | Electric | Subsidiaries
Segment Reporting Information [Line Items]
Depreciation and amortization	324	305	959	904
Operating income/(loss)	834	813	1,337	1,413
CECONY | Gas | Subsidiaries
Segment Reporting Information [Line Items]
Depreciation and amortization	82	74	239	216
Operating income/(loss)	(48)	(34)	490	440
CECONY | Steam | Subsidiaries
Segment Reporting Information [Line Items]
Depreciation and amortization	23	22	69	67
Operating income/(loss)	(58)	(57)	9	1
O&R | Subsidiaries
Segment Reporting Information [Line Items]
Depreciation and amortization	24	23	71	67
Operating income/(loss)	47	49	108	114
O&R | Electric | Subsidiaries
Segment Reporting Information [Line Items]
Depreciation and amortization	18	17	52	48
Operating income/(loss)	55	58	78	86
O&R | Gas | Subsidiaries
Segment Reporting Information [Line Items]
Depreciation and amortization	6	6	19	19
Operating income/(loss)	(8)	(9)	30	28
Operating segment
Segment Reporting Information [Line Items]
Total revenues	3,613	3,333
Operating segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Total revenues	264	222	779	566
Operating segment | Con Edison Transmission
Segment Reporting Information [Line Items]
Total revenues	1	1	3	3
Operating segment | Electric
Segment Reporting Information [Line Items]
Total revenues			10,261	9,286
Operating segment | CECONY | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	3,092	2,872	8,784	8,072
Operating segment | CECONY | Electric | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	2,730	2,562	6,661	6,178
Operating segment | CECONY | Gas | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	307	259	1,730	1,509
Operating segment | CECONY | Steam | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	55	51	393	385
Operating segment | O&R | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	257	238	699	647
Operating segment | O&R | Electric | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	223	208	522	483
Operating segment | O&R | Gas | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	34	30	177	164
Other
Segment Reporting Information [Line Items]
Total revenues	(1)	0	(4)	(2)
Depreciation and amortization	1	0	0	0
Operating income/(loss)	(2)	(1)	(4)	(3)
Other | Con Edison Transmission
Segment Reporting Information [Line Items]
Total revenues			3
Inter-segment | Electric
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Inter-segment | CECONY | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	(25)	(24)	(75)	(74)
Inter-segment | CECONY | Electric | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	5	4	14	13
Inter-segment | CECONY | Gas | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	2	2	6	5
Inter-segment | CECONY | Steam | Subsidiaries
Segment Reporting Information [Line Items]
Total revenues	$ 18	$ 18	$ 55	$ 56

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Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	$ 1,017	$ 675
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(329)	(478)
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/(Liabilities)	181	(366)
Gross Amounts Offset	(108)	3
Net Amounts of Assets/ (Liabilities)	73	(363)
Margin deposits		3
Interest Rate Swap
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	5	0
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(65)	(106)
CECONY | Subsidiaries
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	898	550
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/(Liabilities)	238	(252)
Gross Amounts Offset	(139)	0
Net Amounts of Assets/ (Liabilities)	99	(252)
Margin deposits		3
Clean Energy Businesses | Interest Rate Swap
Net fair value derivative assets/(liabilities)
Notional amount	1,046	863
Fair value of derivative liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(428)	(225)
Gross Amounts Offset	265	(13)
Net Amounts of Assets/ (Liabilities)	(163)	(238)
Fair value of derivative liabilities, Current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(26)	(24)
Fair value of derivative liabilities, Current | CECONY | Subsidiaries
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(158)	(174)
Gross Amounts Offset	44	11
Net Amounts of Assets/ (Liabilities)	(114)	(163)
Fair value of derivative liabilities, Noncurrent
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(183)	(207)
Gross Amounts Offset	17	(33)
Net Amounts of Assets/ (Liabilities)	(166)	(240)
Fair value of derivative liabilities, Noncurrent | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(39)	(82)
Fair value of derivative liabilities, Noncurrent | CECONY | Subsidiaries
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(125)	(114)
Gross Amounts Offset	28	9
Net Amounts of Assets/ (Liabilities)	(97)	(105)
Total fair value of derivative liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(611)	(432)
Gross Amounts Offset	282	(46)
Net Amounts of Assets/ (Liabilities)	(329)	(478)
Total fair value of derivative liabilities | CECONY | Subsidiaries
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/(Liabilities)	(283)	(288)
Gross Amounts Offset	72	20
Net Amounts of Assets/ (Liabilities)	(211)	(268)
Total fair value of derivative assets, Noncurrent | Interest Rate Swap
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	5
Fair value of derivative assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	652	44
Gross Amounts Offset	(375)	14
Net Amounts of Assets/ (Liabilities)	277	58
Fair value of derivative assets, Current | CECONY | Subsidiaries
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	407	20
Gross Amounts Offset	(183)	(12)
Net Amounts of Assets/ (Liabilities)	224	8
Total fair value of derivative assets, Noncurrent
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	140	22
Gross Amounts Offset	(15)	35
Net Amounts of Assets/ (Liabilities)	125	57
Total fair value of derivative assets, Noncurrent | CECONY | Subsidiaries
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	114	16
Gross Amounts Offset	(28)	(8)
Net Amounts of Assets/ (Liabilities)	86	8
Total fair value of derivative assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	792	66
Gross Amounts Offset	(390)	49
Net Amounts of Assets/ (Liabilities)	402	115
Total fair value of derivative assets | CECONY | Subsidiaries
Fair value of derivative assets
Gross Amounts of Recognized Assets/(Liabilities)	521	36
Gross Amounts Offset	(211)	(20)
Net Amounts of Assets/ (Liabilities)	$ 310	$ 16

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Derivative Instruments and Hedging Activities - Realized and Unrealized Gains (Losses) on Commodity Derivatives (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ 366	$ 43	$ 549	$ 38
Total deferred gains/(losses)	(48)	(47)	(21)	(224)
Net deferred gains/(losses)	318	(4)	528	(186)
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	(9)	5	32	(87)
Gas purchased for resale
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	2	0	4	(3)
Non-utility revenue
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	(23)	(2)	(22)	3
Other operations and maintenance expense
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	1	0	5	(5)
Other interest expense
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	11	7	45	(82)
Deferred Derivative Gains, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	296	26	443	23
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	70	17	106	15
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(4)	(9)	25	12
Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	17	(23)	(30)	(163)
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(61)	(15)	(16)	(73)
CECONY | Subsidiaries
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	345	40	512	34
Total deferred gains/(losses)	(45)	(42)	(20)	(205)
Net deferred gains/(losses)	300	(2)	492	(171)
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	1	0	5	(5)
CECONY | Gas purchased for resale | Subsidiaries
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	0	0	0	0
CECONY | Non-utility revenue | Subsidiaries
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	0	0	0	0
CECONY | Other operations and maintenance expense | Subsidiaries
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	1	0	5	(5)
CECONY | Other interest expense | Subsidiaries
Pre-tax gains/(losses) recognized in income
Total pre-tax gains/(losses) recognized in income	0	0	0	0
CECONY | Deferred Derivative Gains, Current | Subsidiaries
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	279	24	415	20
CECONY | Deferred Derivative Gains, Noncurrent | Subsidiaries
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	66	16	97	14
CECONY | Deferred Derivative Losses, Current | Subsidiaries
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(3)	(11)	22	9
CECONY | Recoverable Energy Costs, Current | Subsidiaries
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	13	(19)	(29)	(144)
CECONY | Deferred Derivative Losses, Noncurrent | Subsidiaries
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (55)	$ (12)	$ (13)	$ (70)

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Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details)	Sep. 30, 2021 MW gal MWh MMBTU
Electric Energy (MWh)
Derivatives, Fair Value [Line Items]
Notional amount | MWh	23,870,400
Capacity (MW)
Derivatives, Fair Value [Line Items]
Notional amount | MW	39,914
Natural Gas (Dt)
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	280,838,997
Refined Fuels (gallons)
Derivatives, Fair Value [Line Items]
Notional amount | gal	4,704,000
CECONY | Electric Energy (MWh) | Subsidiaries
Derivatives, Fair Value [Line Items]
Notional amount | MWh	21,401,150
CECONY | Capacity (MW) | Subsidiaries
Derivatives, Fair Value [Line Items]
Notional amount | MW	29,700
CECONY | Natural Gas (Dt) | Subsidiaries
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	261,010,000
CECONY | Refined Fuels (gallons) | Subsidiaries
Derivatives, Fair Value [Line Items]
Notional amount | gal	4,704,000

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Derivative Instruments and Hedging Activities - Additional Information (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($)
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 689
Makeup of net credit exposure independent system operators	95
Makeup of net credit exposure non-investment grade/non-rated counterparties	103
Makeup of net credit exposure with commodity exchange brokers	160
Makeup of net credit exposure with investment-grade counterparties	331
CECONY | Subsidiaries
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	424
Makeup of net credit exposure with commodity exchange brokers	131
Makeup of net credit exposure with investment-grade counterparties	$ 293

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Derivative Instruments and Hedging Activities - Credit-Risk-Related Contingent Features (Details) $ in Millions	Sep. 30, 2021 USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 211
Collateral posted	170
Additional collateral for non-derivative transactions without extended unsecured credit	14
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	24
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	83
Derivatives in net asset position additional collateral	72
CECONY | Subsidiaries
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	176
Collateral posted	165
CECONY | Downgrade One Level from Current Ratings | Subsidiaries
Derivatives, Fair Value [Line Items]
Additional collateral	4
CECONY | Downgrade to Below Investment Grade from Current Ratings | Subsidiaries
Derivatives, Fair Value [Line Items]
Additional collateral	$ 54

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Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 1,017	$ 675
Derivative liabilities	329	478
CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	898	550
Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(380)	53
Derivative liabilities	(272)	46
Netting Adjustment | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(201)	(16)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	694	450
Derivative liabilities	40	7
Level 1 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	602	426
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	674	168
Derivative liabilities	527	402
Level 2 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	495	140
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	29	4
Derivative liabilities	34	23
Level 3 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2	0
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	397	118
Derivative liabilities	264	372
Transfer out of level 3	1
Commodity | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	310	19
Derivative liabilities	211	268
Transfer out of level 3	1
Commodity | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(380)	53
Derivative liabilities	(272)	46
Commodity | Netting Adjustment | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(201)	(16)
Derivative liabilities	(61)	(19)
Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	215	19
Derivative liabilities	40	7
Commodity | Level 1 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	142	15
Derivative liabilities	0	3
Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	533	42
Derivative liabilities	462	296
Commodity | Level 2 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	367	20
Derivative liabilities	253	274
Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	29	4
Derivative liabilities	34	23
Commodity | Level 3 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	2	0
Derivative liabilities	19	10
Interest rate swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	5	0
Derivative liabilities	65	106
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	5	0
Derivative liabilities	65	106
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	615	557
Other | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	588	531
Other | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Other | Netting Adjustment | CECONY | Subsidiaries
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	479	431
Other | Level 1 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	460	411
Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	136	126
Other | Level 2 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	128	120
Other | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Other | Level 3 | CECONY | Subsidiaries
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 0	$ 0

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Fair Value Measurements - Schedule of Commodity Derivatives (Details) $ in Millions	Sep. 30, 2021 USD ($) $ / MWh $ / kW-month	Dec. 31, 2020 USD ($)
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1,017	$ 675
CECONY | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	898	550
Level 3
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	29	4
Level 3 | CECONY | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	2	$ 0
Level 3 | Electricity | Forward energy prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 11
Level 3 | Electricity | Forward energy prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	15.00
Level 3 | Electricity | Forward energy prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	130.75
Level 3 | Electricity | Forward energy prices | CECONY | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (9)
Level 3 | Electricity | Forward energy prices | CECONY | Minimum | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	26.80
Level 3 | Electricity | Forward energy prices | CECONY | Maximum | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	98.51
Level 3 | Electricity | Forward capacity prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (17)
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	0.26
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	12.93
Level 3 | Electricity | Forward capacity prices | CECONY | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (10)
Level 3 | Electricity | Forward capacity prices | CECONY | Minimum | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	0.70
Level 3 | Electricity | Forward capacity prices | CECONY | Maximum | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	12.93
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	(4.21)
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	10.11
Level 3 | Commodity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (5)
Level 3 | Commodity | CECONY | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(17)
Level 3 | Transmission Congestion Contracts | Inter-zonal forward price curves adjusted for historical zonal losses | CECONY | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 2
Level 3 | Transmission Congestion Contracts | Inter-zonal forward price curves adjusted for historical zonal losses | CECONY | Minimum | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	0.63
Level 3 | Transmission Congestion Contracts | Inter-zonal forward price curves adjusted for historical zonal losses | CECONY | Maximum | Subsidiaries
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	5.63

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Fair Value Measurements - Reconciliation of Assets and Liabilities Measured at Level 3 Fair Value (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ (9)	$ (14)	$ (19)	$ (16)
Included in earnings	21	0	20	(7)
Included in regulatory assets and liabilities	(17)	(3)	(9)	(3)
Settlements	0	0	3	9
Ending balance	(5)	(17)	(5)	(17)
CECONY | Subsidiaries
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	(7)	(7)	(10)	(6)
Included in earnings	1	0	(2)	(3)
Included in regulatory assets and liabilities	(11)	(1)	(7)	(3)
Settlements	0	(1)	2	3
Ending balance	$ (17)	$ (9)	$ (17)	$ (9)

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Fair Value Measurements - Additional Information (Details) - Clean Energy Businesses - Non-utility revenue - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative assets and liabilities	$ 20	$ 1
Change in fair value relating to Level 3 commodity derivative assets and liabilities			$ 24	$ 2

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Variable Interest Entities - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Jun. 30, 2021
Clean Energy Businesses
Variable Interest Entity [Line Items]
Equity method investments	$ 7		$ 7		$ 11
Variable Interest Entity, Primary Beneficiary | Tax Equity Projects
Variable Interest Entity [Line Items]
Income (loss) before tax	14		(20)
Net income (loss)	(11)		27
Variable Interest Entity, Primary Beneficiary | Tax Equity Investors | Tax Equity Construction Projects
Variable Interest Entity [Line Items]
Income (loss) before tax	(74)		(127)
Net income (loss)	$ 56		96
Variable Interest Entity, Primary Beneficiary | Tax Equity Investors | Tax Equity Projects
Variable Interest Entity [Line Items]
Income (loss) before tax		$ 9	6	$ 29
Net income (loss)		(7)	$ (8)	(38)
Variable Interest Entity, Primary Beneficiary | Con Edison Development | Tax Equity Projects
Variable Interest Entity [Line Items]
Income (loss) before tax		(7)		(2)
Net income (loss)		$ 5		$ 3
Percentage of variable interests (less than)			100.00%

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Variable Interest Entities - Net Assets (Details) - USD ($) $ in Millions	Sep. 30, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Noncontrolling interest	$ 340	$ 218
Great Valley Solar
Variable Interest Entity [Line Items]
Non-utility property, less accumulated depreciation	278	284
Other assets	40	39
Total assets	318	323
Other liabilities	14	13
Total liabilities	14	13
Accumulated depreciation	24	18
Great Valley Solar | Tax Equity Investors
Variable Interest Entity [Line Items]
Noncontrolling interest	88	82
Copper Mountain - Mesquite Solar
Variable Interest Entity [Line Items]
Non-utility property, less accumulated depreciation	435	446
Other assets	174	176
Total assets	609	622
Other liabilities	79	71
Total liabilities	79	71
Accumulated depreciation	40	30
Copper Mountain - Mesquite Solar | Tax Equity Investors
Variable Interest Entity [Line Items]
Noncontrolling interest	122	$ 134
CED Nevada Virginia
Variable Interest Entity [Line Items]
Non-utility property, less accumulated depreciation	647
Other assets	57
Total assets	704
Other liabilities	328
Total liabilities	328
Noncontrolling interest	128
Accumulated depreciation	$ 5

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Dispositions (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		9 Months Ended
	Jul. 31, 2021	May 31, 2021	Mar. 31, 2022	Sep. 30, 2021	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of projects sold				$ 43,536	$ 43,536			$ 42,024
Stagecoach Gas Services LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Equity method investments						$ 630	$ 667
Loss on sale of investment (pre-tax)					211
Loss on sale of investment					147
Subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of projects sold				40,983	40,983			$ 39,552
Clean Energy Businesses | Subsidiaries
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Carrying value of projects sold						$ 180
Gain (loss) on sale of projects				3	3
Gain on sale, after tax				2	2
Equity method investments				$ 11	$ 11
Con Edison Transmission | Subsidiaries | Stagecoach Gas Services LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 1,195	$ 1,225
Con Edison Transmission | Subsidiaries | Stagecoach Gas Services LLC | Scenario, Forecast
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale			$ 30