10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

___________________________________________________ 

FORM 10-K

___________________________________________________  

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

FOR THE FISCAL YEAR ENDED DECEMBER 31, 2020

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 1-14514

Consolidated Edison, Inc.

Exact name of registrant as specified in its charter

and principal office address and telephone number

New York	13-3965100
State of Incorporation	I.R.S. Employer ID. Number

4 Irving Place,
New York,	New York	10003
(212)	460-4600

 ___________________________________________________  

Commission File Number 1-1217

Consolidated Edison Company of New York, Inc.

Exact name of registrant as specified in its charter

and principal office address and telephone number

New York	13-5009340
State of Incorporation	I.R.S. Employer ID. Number

4 Irving Place,
New York,	New York	10003
(212)	460-4600

 ___________________________________________________  

                                                                                                                         CON EDISON ANNUAL REPORT 2020 1

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)

Securities Registered Pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Consolidated Edison, Inc. (Con Edison)	Yes	x	No	¨
Consolidated Edison Company of New York, Inc. (CECONY)	Yes	x	No	¨

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

Con Edison	Yes	¨	No	x
CECONY	Yes	¨	No	x

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.

Con Edison	Yes	x	No	¨
CECONY	Yes	x	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	x	No	¨
CECONY	Yes	x	No	¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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	☐

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 has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☒

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

Con Edison	Yes	☐	No	x
CECONY	Yes	☐	No	x

The aggregate market value of the common equity of Con Edison held by non-affiliates of Con Edison, as of June 30, 2020, was approximately $24.0 billion.

As of January 31, 2021, Con Edison had outstanding 342,419,162 Common Shares ($.10 par value).

2 CON EDISON ANNUAL REPORT 2020

All of the outstanding common equity of CECONY is held by Con Edison.

Documents Incorporated By Reference

Portions of Con Edison’s definitive proxy statement for its Annual Meeting of Stockholders to be held on May 17, 2021, to be filed with the Commission pursuant to Regulation 14A, not later than 120 days after December 31, 2020, is incorporated in Part III of this report.

Filing Format

This Annual Report on Form 10-K 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. CECONY meets the conditions set forth in General Instruction (I)(1)(a) and (b) of Form 10-K and is therefore filing this Form 10-K with the reduced disclosure format.

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.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 3

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, including Consolidated Edison Development, Inc., Consolidated Edison Energy, Inc. and Consolidated Edison Solutions, Inc.
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
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
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
NYSERDA	New York State Energy Research and Development Authority
NYSPSC	New York State Public Service Commission
NYSRC	New York State Reliability Council, LLC
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
OCI	Other Comprehensive Income
VIE	Variable Interest Entity

4 CON EDISON ANNUAL REPORT 2020

 

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
Mlb	Thousands of pounds
MMlb	Million pounds
MVA	Megavolt ampere
MW	Megawatt or thousand kilowatts
MWh	Megawatt hour
Other
AMI	Advanced Metering Infrastructure
CLCPA	Climate Leadership and Community Protection Act
COSO	Committee of Sponsoring Organizations of the Treadway Commission
COVID-19	Coronavirus Disease 2019
DER	Distributed energy resources
Fitch	Fitch Ratings
LTIP	Long Term Incentive Plan
Moody’s	Moody’s Investors Service
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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 5

TABLE OF CONTENTS

		PAGE
Introduction		7
Available Information		11
Forward-Looking Statements		11
Non-GAAP Financial Measures		11
Part I
Item 1:	Business	16
Item 1A:	Risk Factors	45
Item 1B:	Unresolved Staff Comments	49
Item 2:	Properties	49
Item 3:	Legal Proceedings	50
Item 4:	Mine Safety Disclosures	50
	Information about our Executive Officers	51
Part II
Item 5:	Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	52
Item 6:	Selected Financial Data	53
Item 7:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	54
Item 7A:	Quantitative and Qualitative Disclosures about Market Risk	92
Item 8:	Financial Statements and Supplementary Data	93
Item 9:	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	191
Item 9A:	Controls and Procedures	191
Item 9B:	Other Information	191
Part III
Item 10:	Directors, Executive Officers and Corporate Governance	192
Item 11:	Executive Compensation	192
Item 12:	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	192
Item 13:	Certain Relationships and Related Transactions, and Director Independence	192
Item 14:	Principal Accounting Fees and Services	192
Part IV
Item 15:	Exhibits and Financial Statement Schedules	194
Item 16:	Form 10-K Summary	199
	Signatures	201

6 CON EDISON ANNUAL REPORT 2020

Introduction

This introduction contains certain information about Con Edison and its subsidiaries, including CECONY. This introduction is not a summary and should be read together with, and is qualified in its entirety by reference to, the more detailed information appearing elsewhere or incorporated by reference in this report.

Con Edison’s mission is to provide energy services to our customers safely, reliably, efficiently and in keeping with our vision for a clean energy future; to provide a workplace that embraces diversity and inclusion and allows employees to realize their full potential; to provide a fair return to our investors; and to improve the quality of life in the communities we serve. The company has ongoing programs designed to support each component of its mission, including initiatives focused on safety, operational excellence and the customer experience.

Con Edison is a holding company that owns:

•Consolidated Edison Company of New York, Inc. (CECONY), which provides electric service and gas service in New York City and Westchester County and steam service in parts of Manhattan;

•Orange & Rockland Utilities, Inc., which along with its utility subsidiary, Rockland Electric Company (together referred to herein as O&R), provides electric service in southeastern New York and northern New Jersey and gas service in southeastern New York (O&R, together with CECONY referred to as the Utilities);

•Con Edison Clean Energy Businesses, Inc., which 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 Clean Energy Businesses, Inc., together with its subsidiaries referred to as the Clean Energy Businesses); and

•Con Edison Transmission, Inc., which through its subsidiaries, invests in electric transmission facilities and holds investments in gas pipeline and storage facilities (Con Edison Transmission, Inc., together with its subsidiaries referred to as Con Edison Transmission).

Con Edison anticipates that the Utilities, which are subject to extensive regulation, will continue to provide substantially all of its earnings over the next few years. The Utilities have approved rate plans that are generally designed to cover each company’s cost of service, including capital and other costs of each company’s energy delivery systems. The Utilities recover from their full-service customers (who purchase energy from them), generally on a current basis, the cost the Utilities pay for energy and charge all of their customers the cost of delivery service. See "Utility Regulation" in Item 1, "Risk Factors" in Item 1A and "Rate Plans" in Note B to the financial statements in Item 8.

Selected Financial Data

Con Edison

	For the Year Ended December 31,
(Millions of Dollars, except per share amounts)	2016	2017		2018		2019		2020
Operating revenues	$12,075	$12,033		12,337		12,574		12,246
Energy costs	3,088	2,625		2,948		2,633		2,283
Operating income (f)	2,780	2,774		2,664		2,676		2,654
Net income for common stock	1,245	1,525	(e)	1,382	(e)	1,343		1,101
Total assets	48,255	48,111	(a)	53,920	(b)	58,079	(c)	62,895	(d)
Long-term debt	14,735	14,731		17,495		18,527		20,382
Total equity	14,306	15,425		16,839		18,213		19,065
Net Income per common share – basic	$4.15	$4.97		$4.43		$4.09		$3.29
Net Income per common share – diluted	$4.12	$4.94		$4.42		$4.08		$3.28
Dividends declared per common share	$2.68	$2.76		$2.86		$2.96		$3.06
Book value per share	$46.91	$49.72		$52.46		$54.75		$55.70
Average common shares outstanding (millions)	300	307		312		329		335

(a)Reflects a $2,384 million increase in net plant, offset by decreases in regulatory assets resulting from the enactment of the federal Tax Cuts and Jobs Act of 2017, as enacted on December 22, 2017 (TCJA) of $2,418 million (including the netting of $1,168 million against the regulatory liability for future income tax) and unrecognized pension and other postretirement costs of $348 million. See Notes B, E, F and L to the financial statements in Item 8.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 7

(b)Reflects a $4,149 million increase in net plant, offset by a $288 million decrease in regulatory assets for unrecognized pension and other postretirement costs. See Notes B, E, and F to the financial statements in Item 8.

(c)Reflects a $2,140 million increase in net plant and a $303 increase in regulatory assets for unrecognized pension and other postretirement costs. See Notes B, E, and F to the financial statements in Item 8.

(d)Reflects a $2,666 million increase in net plant and a $700 million increase in regulatory assets for unrecognized pension and other postretirement costs. See Notes B, E, and F to the financial statements in Item 8.

(e)In 2017, upon enactment of the TCJA, Con Edison re-measured its deferred tax assets and liabilities based upon the 21 percent corporate income tax rate under the TCJA. As a result, Con Edison decreased its net deferred tax liabilities by $5,312 million, recognized $259 million (or $0.85 per share) in net income, decreased its regulatory asset for future income tax by $1,250 million, decreased its regulatory asset for revenue taxes by $90 million, and accrued a regulatory liability for federal income tax rate change of $3,713 million. In 2018, Con Edison recognized $42 million of income tax expense resulting from a re-measurement of its deferred tax assets and liabilities following the issuance of proposed TCJA regulations. See “Other Regulatory Matters” in Note B and Note L to the financial statements in Item 8.

(f)Excludes the non-service components of pension and other postretirement benefits. See Notes E and F to the financial statements in Item 8.

CECONY 

	For the Year Ended December 31,
(Millions of Dollars)	2016	2017		2018		2019		2020
Operating revenues	$10,165	$10,468		$10,680		$10,821		$10,647
Energy costs	2,059	2,141		2,339		2,170		2,014
Operating income (e)	2,451	2,549		2,354		2,348		2,310
Net income	1,056	1,104		1,196		1,250		1,185
Total assets	40,856	40,451	(a)	43,108	(b)	46,557	(c)	50,967	(d)
Long-term debt	12,073	12,065		13,676		14,614		16,149
Shareholder’s equity	11,829	12,439		12,910		14,147		14,849

(a)Reflects a $2,090 million increase in net plant, offset by decreases in regulatory assets resulting from the enactment of the TCJA of $2,305 million (including the netting of $1,123 million against the regulatory liability for future income tax) and unrecognized pension and other postretirement costs of $354 million. See Notes B, E and F to the financial statements in Item 8.

(b)Reflects a $2,165 million increase in net plant and a $265 million decrease in regulatory assets for unrecognized pension and other postretirement costs. See Notes B, E and F to the financial statements in Item 8.

(c)Reflects a $2,040 million increase in net plant and a $292 million increase in regulatory assets for unrecognized pension and other postretirement costs. See Notes B, E and F to the financial statements in Item 8.

(d)Reflects a $2,140 million increase in net plant and a $662 million increase in regulatory assets for unrecognized pension and other postretirement costs. See Notes B, E and F to the financial statements in Item 8.

(e)Excludes the non-service components of pension and other postretirement benefits. See Notes E and F to the financial statements in Item 8.

Significant Developments and Outlook

•Con Edison reported 2020 net income of $1,101 million or $3.29 a share compared with $1,343 million or $4.09 a share in 2019. Adjusted earnings were $1,399 million or $4.18 a share in 2020 compared with $1,438 million or $4.38 a share in 2019. See “Results of Operations” in Item 7 and “Non-GAAP Financial Measures” below.

•In 2020, the Utilities invested $3,466 million to upgrade and reinforce their energy delivery systems, the Clean Energy Businesses invested $616 million in renewable electric production projects and Con Edison Transmission invested $3 million primarily in the electric transmission business. For 2021, 2022 and 2023 the Utilities expect to invest $3,721 million, $3,478 million and $3,724 million, respectively, for their energy delivery systems, the Clean Energy Businesses expect to invest $250 million, $400 million and $400 million, respectively, in renewable electric production projects and Con Edison Transmission expects to invest $47 million, $65 million and $47 million, respectively, primarily in the electric transmission business. See "Capital Requirements and Resources - Capital Requirements" in Item 1.

•Con Edison plans to meet its capital requirements for 2021 through 2023, through internally-generated funds and the issuance of long-term debt and common equity. See “Capital Requirements and Resources - Capital Requirements” in Item 1. 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.

8 CON EDISON ANNUAL REPORT 2020

•CECONY forecasts average annual growth in peak demand in its service area at design conditions over the next five years for electricity and gas to be approximately 0.8 percent and 1.4 percent, respectively, and an average annual decrease in steam peak demand in its service area at design conditions over the next five years to be approximately 0.4 percent. O&R forecasts an average annual decrease in electric peak demand in its service area at design conditions over the next five years to be approximately 0.5 percent and average annual growth in gas peak demand in its service area over the next five years at design conditions to be approximately 0.2 percent. See “The Utilities” in Item 1.

•CECONY established a gas moratorium in March 2019 on new gas service in most of Westchester County. CECONY filed a gas planning analysis with the NYSPSC in July 2020 stating the moratorium could be lifted when increased pipeline capacity is achieved or peak demand is reduced to a level that would enable the company to lift the moratorium and that it is monitoring gas supply constraint in the New York City portion of its service territory. See "The Utilities" in Item 1.

•In 2020, due to the COVID-19 pandemic, 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 the State of New York enacted a law prohibiting New York utilities, including CECONY and O&R, from disconnecting residential customers during the COVID-19 state of emergency. For the year ended 2020, the reserve increases to the allowance for uncollectible accounts associated with the COVID-19 pandemic for CECONY electric and gas operations and O&R electric operations were $73 million and $2 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. See "COVID-19 Regulatory Matters" in Note B to the financial statements in Item 8.

•In November 2020, the New York State Public Service Commission (NYSPSC) issued two separate show cause orders in its proceedings investigating: (1) the New York utilities’ preparation for and response to Tropical Storm Isaias and the resulting power outages in August 2020 and (2) the July 2019 power outages on the west side of Manhattan and in the Flatbush area of Brooklyn. See "Other Regulatory Matters" in Note B to the financial statements in Item 8.

•The NYSPSC also continued its proceedings related to income tax accounting and a July 2018 CECONY steam rupture and concluded its investigations into the Utilities' preparation and response to the March 2018 Winter Storms Riley and Quinn and its proceeding against CECONY for alleged violations of gas operator qualification, performance, and inspection requirements. See "Other Regulatory Matters" in Note B to the financial statements in Item 8.

•In 2020, the NYSPSC continued its Reforming the Energy Vision (REV) and related proceedings. See "Environmental Matters - Clean Energy Future - Reforming the Energy Vision" in Item 1. In July 2020, the NYSPSC established a light-duty electric vehicle make-ready program that includes budgets of $290 million and $24 million for CECONY and O&R, respectively, through 2025 for electric vehicle infrastructure for fast charger stations, fleet assessment services for customers interested in fleet electrification and future-proofing so that components can accommodate updates to the quantity or charging capacity of the station. See "Environmental Matters - Clean Energy Future" in Item 1.

•The Clean Energy Businesses increased their renewable energy portfolio by 186 MW AC, resulting in a year-end installed capacity of 2,868 MW AC, bringing the annual renewable energy production for 2020 to over 7 terawatt hours. See "Clean Energy Businesses" in Item 1.

•In January 2019, Pacific Gas and Electric Company (PG&E) filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code. The output of certain of the Clean Energy Businesses' renewable electric production projects is sold to PG&E under long-term power purchase agreements. As a result of the PG&E bankruptcy, distributions from the related projects to the Clean Energy Businesses were restricted and PG&E-related project debt was reclassified on Con Edison's consolidated balance sheet from long-term debt to long-term debt due within one year. In July 2020, PG&E’s plan of reorganization became effective and the Clean Energy Businesses began receiving previously restricted distributions and all related project debt with a maturity longer than one year was reclassified to long-term debt. See "Clean Energy Businesses - Renewable Electric Production" in Item 1 and "Long-Lived and Intangible Assets" in Note A.

•Con Edison Gas Pipeline and Storage, LLC (CET Gas) recorded a pre-tax impairment loss of $320 million ($223 million after-tax) for the year ended December 31, 2020 that reduced the carrying value of its investment

                                                                                                                         CON EDISON ANNUAL REPORT 2020 9

in Mountain Valley Pipeline LLC (MVP), a joint venture developing a proposed 300-mile gas transmission project in West Virginia and Virginia from $662 million to $342 million. See “Investments” in Note A to the financial statements in Item 8.

•CET Gas is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC, a joint venture that owns and operates an existing gas pipeline and storage business located in northeastern Pennsylvania and the southern tier of New York. See “Con Edison Transmission,” in Item 1.

10 CON EDISON ANNUAL REPORT 2020

Available Information

Con Edison and CECONY file annual, quarterly and current reports and other information, and Con Edison files proxy statements, with the Securities and Exchange Commission (SEC). The SEC maintains an Internet site at www.sec.gov that contains reports, proxy statements, and other information regarding issuers (including Con Edison and CECONY) that file electronically with the SEC.

This information the Companies file with the SEC is also available free of charge on or through the investor information section of their websites as soon as reasonably practicable after the reports are electronically filed with, or furnished to, the SEC. Con Edison’s internet website is at: www.conedison.com; and CECONY’s is at: www.coned.com.

The "About Us - Corporate Governance" section of Con Edison’s website includes the company’s Standards of Business Conduct (its code of ethics) and amendments or waivers of the standards for executive officers or directors, corporate governance guidelines and the charters of the following committees of the company’s Board of Directors: Audit Committee, Corporate Governance and Nominating Committee, Management Development and Compensation Committee, and Safety, Environment, Operations, and Sustainability Committee. This information is available in print to any shareholder who requests it. Requests should be directed to: Corporate Secretary, Consolidated Edison, Inc., 4 Irving Place, New York, NY 10003.

The "About Us - Sustainability Report” section of Con Edison’s website includes “Our Sustainable Future,” the company’s 2019 sustainability report.

Information on the Companies’ websites is not incorporated herein.

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 expectations and not facts. Words such as "forecasts," "expects," "estimates," "anticipates," "intends," "believes," "plans," "will," "target," and similar expressions identify forward-looking statements. The forward-looking statements reflect information available and assumptions at the time the statements are made, and 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, those discussed under “Risk Factors,” in Item 1A.

Non-GAAP Financial Measures

Adjusted earnings and adjusted earnings per share are financial measures that are not determined in accordance with generally accepted accounting principles in the United States of America (GAAP). These non-GAAP financial measures should not be considered as an alternative to net income for common stock or net income per share, respectively, each of which is an indicator of financial performance determined in accordance with GAAP. Adjusted earnings and adjusted earnings per share exclude from net income and net income per share, respectively, certain other items that the company does not consider indicative of its ongoing financial performance. Management uses these non-GAAP financial measures to facilitate the analysis of the company's financial performance as compared to its internal budgets and previous financial results. Management also uses these non-GAAP financial measures to communicate to investors and others the company’s expectations regarding its future earnings and dividends on its common stock. Management believes that these non-GAAP financial measures also are useful and meaningful to investors to facilitate their analysis of the company's financial performance. The following table is a reconciliation of Con Edison’s reported net income for common stock to adjusted earnings and reported earnings per share to adjusted earnings per share. 

                                                                                                                         CON EDISON ANNUAL REPORT 2020 11

(Millions of Dollars, except per share amounts)	2016	2017	2018	2019	2020
Reported net income for common stock – GAAP basis	$1,245	$1,525	$1,382	$1,343	$1,101
Income tax effect of the Tax Cuts and Jobs Act (a)	—	(259)	42	—	—
Gain on sale of solar electric production projects (pre-tax)	—	(2)	—	—	—
Income taxes (b)	—	1	—	—	—
Gain on sale of solar electric production projects (net of tax)	—	(1)		—	—
Gain on sale of the Clean Energy Businesses' retail electric supply business (pre-tax)	(104)	—	—	—	—
Income taxes (b)	48	—	—	—	—
Gain on sale of the Clean Energy Businesses' retail electric supply business (net of tax)	(56)	—	—	—	—
Goodwill impairment related to the Clean Energy Businesses' energy service business (pre-tax)	15	—	—	—	—
Income taxes (b)	(3)	—	—	—	—
Goodwill impairment related to the Clean Energy Businesses' energy service business (net of tax)	12	—	—	—	—
Gain on acquisition of Sempra Solar Holdings, LLC, net of transaction costs (pre-tax) (c)	—	—	(114)	—	—
Income taxes (b)	—	—	33	—	—
Gain on acquisition of Sempra Solar Holdings, LLC, net of transaction costs (net of tax) (c)	—	—	(81)	—	—
Impairment loss related to investment in Mountain Valley Pipeline, LLC (pre-tax) (d)	—	—	—	—	320
Income taxes (b)	—	—	—	—	(97)
Impairment loss related to investment in Mountain Valley Pipeline, LLC (net of tax) (d)	—	—	—		223
HLBV effects of the Clean Energy Businesses (pre-tax) (e)	—	—	—	98	44
Income taxes (b)	—	—	—	(24)	(12)
HLBV effects of the Clean Energy Businesses (net of tax) (e)	—	—	—	74	32
Net mark-to-market effects of the Clean Energy Businesses (pre-tax)	(5)	(1)	8	27	57
Income taxes (b)	2	—	(2)	(6)	(14)
Net mark-to-market effects of the Clean Energy Businesses (net of tax)	(3)	(1)	6	21	43
Adjusted earnings (Non-GAAP)	$1,198	$1,264	$1,349	$1,438	$1,399
Reported earnings per share – GAAP basis (basic)	$4.15	$4.97	$4.43	$4.09	$3.29
Income tax effect of the Tax Cuts and Jobs Act (a)	—	(0.85)	0.14	—	—
Gain on sale of solar electric production projects (pre-tax)	—	—	—	—	—
Income taxes (b)	—	—	—	—	—
Gain on sale of solar electric production projects (net of tax)	—	—	—	—	—
Gain on sale of the Clean Energy Businesses' retail electric supply business (pre-tax)	(0.35)	—	—	—	—
Income taxes (b)	0.16	—	—	—	—
Gain on sale of the Clean Energy Businesses' retail electric supply business (net of tax)	(0.19)	—	—	—	—
Goodwill impairment related to the Clean Energy Businesses' energy service business (pre-tax)	0.07	—	—	—	—
Income taxes (b)	(0.03)	—	—	—	—
Goodwill impairment related to the Clean Energy Businesses' energy service business (net of tax)	0.04	—	—	—	—
Gain on acquisition of Sempra Solar Holdings, LLC, net of transaction costs (pre-tax) (c)	—	—	(0.36)	—	—
Income taxes (b)	—	—	0.10	—	—
Gain on acquisition of Sempra Solar Holdings, LLC, net of transaction costs (net of tax) (c)	—	—	(0.26)	—	—
Impairment loss related to investment in Mountain Valley Pipeline, LLC (pre-tax) (d)	—	—	—	—	0.95
Income taxes (b)	—	—	—	—	(0.29)
Impairment loss related to investment in Mountain Valley Pipeline, LLC (net of tax) (d)	—	—		—	0.66
HLBV effects of the Clean Energy Businesses (pre-tax) (e)	—	—	—	0.31	0.14
Income taxes (b)	—	—	—	(0.09)	(0.04)
HLBV effects of the Clean Energy Businesses (net of tax) (e)	—	—	—	0.22	0.10
Net mark-to-market effects of the Clean Energy Businesses (pre-tax)	(0.02)	—	0.03	0.10	0.18
Income taxes (b)	0.01	—	(0.01)	(0.03)	(0.05)
Net mark-to-market effects of the Clean Energy Businesses	(0.01)	—	0.02	0.07	0.13
Adjusted earnings per share (Non-GAAP)	$3.99	$4.12	$4.33	$4.38	$4.18

12 CON EDISON ANNUAL REPORT 2020

(a)In 2017, upon enactment of the TCJA, Con Edison re-measured its deferred tax assets and liabilities based upon the 21 percent corporate income tax rate under the TCJA. As a result, Con Edison decreased its net deferred tax liabilities by $5,312 million, recognized $259 million (or $0.85 per share) in net income, decreased its regulatory asset for future income tax by $1,250 million, decreased its regulatory asset for revenue taxes by $90 million, and accrued a regulatory liability for federal income tax rate change of $3,713 million. In 2018, Con Edison recognized $42 million of income tax expense resulting from a re-measurement of its deferred tax assets and liabilities following the issuance of the proposed TCJA regulations. See “Other Regulatory Matters” in Note B and Note L to the financial statements in Item 8.

(b)The amount of income taxes was calculated using a combined federal and state income tax rate between 25-27% for the year ended December 31, 2020, a combined federal and state income tax rate between 22-24% for the year ended December 31, 2019, a combined federal and state income tax rate of 28% for the year ended December 31, 2018 and a combined federal and state income tax rate of 40% for the years ended December 31, 2016-2017.

(c)Gain recognized with respect to jointly-owned renewable energy production projects upon completion of the acquisition of Sempra Solar Holdings, LLC, net of transaction costs for the acquisition. See Note V to the financial statements in Item 8.

(d)Loss recognized with respect to the partial impairment of CET Gas' investment in MVP. See "Investments" in Note A to the financial statements in Item 8.

(e)Income attributable to the non-controlling interest of a tax-equity investor in renewable electric production projects accounted for under the hypothetical liquidation at book value (HLBV) method of accounting. See Note R to the financial statements in Item 8.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 13

Item 1:    Business

Contents of Item 1	Page
Overview	16
CECONY	16
Electric	16
Gas	16
Steam	16
O&R	17
Electric	17
Gas	17
Clean Energy Businesses	17
Con Edison Transmission	17
Utility Regulation	17
State Utility Regulation	17
Regulators	17
New York Utility Industry	18
Rate Plans	18
Liability for Service Interruptions	19
Generic Proceedings	19
Federal Utility Regulation	20
New York Independent System Operator (NYISO)	20
Competition	20
The Utilities	21
CECONY	21
Electric Operations	21
Electric Facilities	21
Electric Sales and Deliveries	22
Electric Peak Demand	22
Electric Supply	23
Gas Operations	24
Gas Facilities	24
Gas Sales and Deliveries	24
Gas Peak Demand	25
Gas Supply	25
Steam Operations	25
Steam Facilities	25
Steam Sales and Deliveries	25
Steam Peak Demand and Capacity	26
Steam Supply	26
O&R	26
Electric Operations	26
Electric Facilities	26
Electric Sales and Deliveries	26
Electric Peak Demand	27
Electric Supply	27
Gas Operations	27
Gas Facilities	27
Gas Sales and Deliveries	28
Gas Peak Demand	28
Gas Supply	29

14 CON EDISON ANNUAL REPORT 2020

Contents of Item 1	Page
Clean Energy Businesses	30
Renewable Electric Generation	31
Energy-Related Products and Services	32
Con Edison Transmission	32
CET Electric	32
CET Gas	32
Capital Requirements and Resources	33
Environmental Matters	36
Clean Energy Future	36
Climate Change	39
Environmental Sustainability	40
CECONY	40
O&R	43
Other Federal, State and Local Environmental Provisions	43
State Anti-Takeover Law	44
Human Capital	44

Incorporation By Reference

Information in any item of this report as to which reference is made in this Item 1 is hereby incorporated by reference in this Item 1. The use of terms such as “see” or “refer to” shall be deemed to incorporate into Item 1 at the place such term is used the information to which such reference is made.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 15

PART I

Item 1:    Business

Overview

Consolidated Edison, Inc. (Con Edison), incorporated in New York State in 1997, is a holding company that owns all of the outstanding common stock of Consolidated Edison Company of New York, Inc. (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 “Companies” refers to Con Edison and CECONY.

		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 electric transmission facilities and holds investments in gas pipeline and storage facilities. Con Edison recorded a pre-tax impairment loss of $320 million for the year ended December 31, 2020 that reduced the carrying value of its investment in Mountain Valley Pipeline LLC and is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC. See "Investments" in Note A to the financial statements in Item 8.

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.

Gas

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

Steam

CECONY operates the largest steam distribution system in the United States by producing and delivering approximately 16,554 MMlb of steam annually to approximately 1,576 customers in parts of Manhattan.

16 CON EDISON ANNUAL REPORT 2020

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.

Gas

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

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 facilities and holds investments in gas pipeline and storage facilities 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. CET Gas owns, through subsidiaries, a 50 percent interest in Stagecoach Gas Services, LLC, a joint venture that owns and operates an existing gas pipeline and storage business located in northeastern Pennsylvania and the southern tier of New York. Con Edison is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC. Also, CET Gas and CECONY own 71.2 percent and 28.8 percent interests, respectively, in Honeoye Storage Corporation, which operates a gas storage facility in upstate New York. In addition, CET Gas owns an 11.3 percent interest (that is expected to be reduced to 8.8 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, a joint venture developing a proposed 300-mile gas transmission project in West Virginia and Virginia. CET Gas recorded a pre-tax impairment loss of $320 million ($223 million after-tax) for the year ended December 31, 2020 that reduced the carrying value of its investment in Mountain Valley Pipeline LLC from $662 million to $342 million. See "Investments" in Note A to the financial statements in Item 8 and “Con Edison Transmission,” below. Con Edison Transmission, Inc., together with CET Electric and CET Gas, are referred to in this report as Con Edison Transmission.

Utility Regulation

State Utility Regulation

Regulators

The Utilities are subject to regulation by the NYSPSC, that under the New York Public Service Law, is authorized to set the terms of service and the rates the Utilities charge for providing service in New York. See “Rate Plans,” below and in Note B to the financial statements in Item 8. The NYSPSC also approves the issuance of the Utilities’ securities and transactions between the Utilities and Con Edison and its other subsidiaries. See “Capital Resources,” below and Note T to the financial statements in Item 8. The NYSPSC exercises jurisdiction over the siting of electric transmission lines in New York State (see “Con Edison Transmission,” below) and approves mergers or other business combinations involving New York utilities.

In addition, under the New York Public Service Law, the NYSPSC has the authority to (i) impose penalties on New York utilities, which could be material, for violating state utility laws and regulations and its orders; (ii) review, at least every five years, an electric utility’s capability to provide safe, adequate and reliable service, order the utility to comply with additional and more stringent terms of service than existed prior to the review, assess the continued operation of the utility as the provider of electric service in its service territory and propose, and act upon, such measures as are necessary to ensure safe and adequate service; and (iii) based on findings of repeated violations of the New York Public Service Law or rules or regulations adopted thereto that demonstrate a failure of a combination gas and electric utility to continue to provide safe and adequate service, revoke or modify an operating certificate issued to the utility by the NYSPSC (following consideration of certain factors, including public interest and standards deemed necessary by the NYSPSC to ensure continuity of service, and due process). See "Risk Factors" in Item 1A and “Other Regulatory Matters” and "COVID-19 Regulatory Matters" in Note B to the financial statements in Item 8.

`

                                                                                                                         CON EDISON ANNUAL REPORT 2020 17

In January 2021, Governor Cuomo proposed legislation that, if enacted, would impact New York utilities, including CECONY and O&R, and that would establish an automatic moratorium on utility disconnections for residential and small business customers during certain states of emergency. See "Risk Factors" in Item 1A and “Other Regulatory Matters” in Note B to the financial statements in Item 8. O&R’s New Jersey subsidiary, RECO, is subject to regulation by the New Jersey Board of Public Utilities (NJBPU). The NYSPSC, together with the NJBPU, are referred to herein as state utility regulators.

New York Utility Industry

Restructuring in the 1990s

In the 1990s, the NYSPSC restructured the electric utility industry in the state. In accordance with NYSPSC orders, the Utilities sold all of their electric generating facilities other than those that also produce steam for CECONY’s steam business (see "Electric Operations – Electric Facilities," below) and provided all of their customers the choice to buy electricity or gas from the Utilities or other suppliers (see "Electric Operations – Electric Sales and Deliveries" and "Gas Operations – Gas Sales and Deliveries," below). In 2020, 60 percent of the electricity and 35 percent of the gas CECONY delivered to its customers, and 52 percent of the electricity and 34 percent of the gas O&R delivered to its customers, was purchased by the customers from other suppliers. In addition, the Utilities no longer control and operate their bulk power electric transmission facilities. See “New York Independent System Operator (NYISO),” below.

Following industry restructuring, there were several utility mergers as a result of which substantially all of the electric and gas delivery service in New York State is now provided by one of five investor-owned utility companies – Con Edison, National Grid plc, Avangrid, Inc. (an affiliate of Iberdrola, S.A.), National Fuel Gas Company or CH Energy Group, Inc. (a subsidiary of Fortis Inc.) – or one of two state authorities – New York Power Authority (NYPA) or Long Island Power Authority.

Rate Plans

Investor-owned utilities in the United States provide delivery service to customers according to the terms of tariffs approved by the appropriate state utility regulator. The tariffs include schedules of rates for service that limit the rates charged by the utilities to amounts that the utilities recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. The utilities’ earnings depend on the limits on rates authorized in, and the other provisions of, their rate plans and their ability to operate their businesses in a manner consistent with such rate plans.

The utilities’ rate plans cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator. In New York, either the utility or the NYSPSC can commence a proceeding for a new rate plan, and a new rate plan filed by the utility will generally take effect automatically in approximately 11 months unless prior to such time the NYSPSC approves a rate plan.

In each rate proceeding, rates are determined by the state utility regulator following the submission by the utility of testimony and supporting information, which are subject to review by the staff of the regulator. Other parties with an interest in the proceeding can also review the utility’s proposal and become involved in the rate proceeding. In New York State, the review process is overseen by an administrative law judge who is employed by the NYSPSC. After an administrative law judge issues a recommended decision that generally considers the interests of the utility, the regulatory staff, other parties and legal requisites, the regulator will issue a rate order. The utility and the regulator’s staff and interested parties may enter jointly into a proposed settlement agreement prior to the completion of this administrative process, in which case the agreement could be approved by the regulator with or without modification.

For each rate plan, the revenues needed to provide the utility a return on invested capital is determined by multiplying the utilities’ rate base by the pre-tax weighted average cost of capital determined in the rate plan. In general, rate base, as reflected in a utility's rate plans, is the sum of the utility’s net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. The NYSPSC uses a forecast of the average rate base for the year that new rates would be in effect (rate year). The NJBPU uses the rate base balances that exist at the end of the historical 12-month period on which base rates are set. The capital structure used in the weighted average cost of capital is determined using actual and forecast data for the same time periods as rate base. The costs of long-term debt, customer deposits and the allowed return on common equity represent a combination of actual and forecast financing information. The allowed return on common equity is determined by each state’s respective utility regulator. The NYSPSC’s current methodology for determining the allowed return on common equity assigns a one-third weight to an estimate determined from a capital asset pricing model applied to a peer group of utility companies and a two-thirds weight to an estimate determined from a dividend discount model

18 CON EDISON ANNUAL REPORT 2020

using stock prices and dividend forecasts for a peer group of utility companies. Both methodologies employ market measurements of equity capital to estimate returns rather than the accounting measurements to which such estimates are applied in setting rates.

Pursuant to the Utilities’ rate plans, there generally can be no change to the rates charged to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans.

For information about the Utilities’ rate plans, see Note B to the financial statements in Item 8.

Liability for Service Interruptions

The tariff provisions under which CECONY provides electric, gas and steam service, and O&R provides electric and gas service, limit each company’s liability to pay for damages resulting from service interruptions to circumstances resulting from its gross negligence or willful misconduct. Under RECO's tariff provisions for electric service, the company is not liable for interruptions that are due to causes beyond its control.

CECONY’s tariff for electric service also provides for reimbursement to electric customers for spoilage losses resulting from service interruptions in certain circumstances. In general, the company is obligated to reimburse affected residential and commercial customers for food spoilage of up to approximately $500 and $10,000, respectively, and reimburse affected residential customers for prescription medicine spoilage losses without limitation on amount per claim. The company’s maximum aggregate liability for such reimbursement for an incident is $15 million. The company is not required to provide reimbursement to electric customers for outages attributable to generation or transmission system facilities or events beyond its control, such as storms, provided the company makes reasonable efforts to restore service as soon as practicable.

New York electric utilities are required to provide credits to customers who are without electric service for more than three days. The credit to a customer would equal the portion of the monthly customer charge attributable to the period the customer was without service. If an extraordinary event occurs, the NYSPSC may direct New York gas utilities to implement the same policies.

The NYSPSC has approved a scorecard for use as a guide to assess electric utility performance in restoring electric service during outages that result from a major storm. The scorecard could also be applied by the NYSPSC for other outages or actions. The scorecard includes performance metrics in categories for preparation, operations response, and communications.

Each New York electric utility is required to submit to the NYSPSC annually an emergency response plan for the reasonably prompt restoration of service in the case of widespread outages in the utility’s service territory due to storms or other events beyond the control of the utility. If, after evidentiary hearings or other investigatory proceedings, the NYSPSC finds that the utility failed to implement its plan reasonably, the NYSPSC may deny recovery of any part of the service restoration costs caused by such failure. In May 2020, the NYSPSC approved emergency response plans for CECONY and O&R. In December 2020, CECONY and O&R each submitted updated plans for 2021.

Generic Proceedings

The NYSPSC from time to time conducts “generic” proceedings to consider issues relating to all electric and gas utilities operating in New York State. Proceedings include the REV proceeding and related implementation proceedings, and proceedings relating to data access, retail access, gas planning, energy efficiency and renewable energy programs and climate change risk disclosure. The Utilities are typically active participants in such proceedings.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 19

Federal Utility Regulation

The Federal Energy Regulatory Commission (FERC), among other things, regulates the transmission and wholesale sales of electricity in interstate commerce and the transmission and sale of natural gas for resale in interstate commerce. In addition, the FERC has the authority to impose penalties, which could be substantial, including penalties for the violation of reliability and cyber security rules. Certain activities of the Utilities, the Clean Energy Businesses and Con Edison Transmission are subject to the jurisdiction of the FERC. The Utilities are subject to regulation by the FERC with respect to electric transmission rates and to regulation by the NYSPSC with respect to electric and gas retail commodity sales and local delivery service. As a matter of practice, the NYSPSC has approved delivery service rates for the Utilities that include both transmission and distribution costs. Wholesale energy and capacity products sold by the Clean Energy Businesses to the regional electric markets are subject to FERC jurisdiction as defined by the independent system operator tariffs. The electric and gas transmission projects in which CET Electric and CET Gas invest are also subject to regulation by the FERC. See “Con Edison Transmission,” below.

New York Independent System Operator (NYISO)

The NYISO is a not-for-profit organization that controls and directs the operation of most of the electric transmission facilities in New York State, including those of the Utilities, as an integrated system. It also administers wholesale markets for electricity in New York State and facilitates the construction of new transmission it considers necessary to meet identified reliability, economic or public policy needs. The New York State Reliability Council (NYSRC) promulgates reliability standards subject to FERC oversight, and the NYISO has agreed to comply with those standards. Pursuant to a requirement that is set annually by the NYSRC, the NYISO requires that entities supplying electricity to customers in New York State have generating capacity (owned, procured through the NYISO capacity markets or contracted for) in an amount equal to the peak demand of their customers plus the applicable reserve margin. In addition, the NYISO has determined that entities that serve customers in New York City must procure sufficient capacity from resources that are electrically located in New York City to cover a substantial percentage of the peak demands of their New York City customers. The NYISO also requires entities that serve customers in the Lower Hudson Valley and New York City customers that are served through the Lower Hudson Valley to procure sufficient capacity from resources electrically located in the Lower Hudson Valley. These requirements apply both to regulated utilities such as CECONY and O&R for the customers they supply under regulated tariffs and to other load serving entities that supply customers on market terms. RECO, O&R’s New Jersey subsidiary, provides electric service in a portion of its service territory that has a different independent system operator – PJM Interconnection LLC (PJM). See “CECONY – Electric Operations – Electric Supply” and “O&R – Electric Operations – Electric Supply,” below.

Competition

The subset of distributed energy resources (DER) that produce electricity are collectively referred to as distributed generation (DG). DG includes solar energy production facilities, fuel cells, and micro-turbines, and provides an alternative source of electricity for the Utilities’ electric delivery customers. Energy storage, though not a form of DG, is also a source of electricity for the Utilities’ electric delivery customers. Typically, customers with DG remain connected to the utility’s delivery system and pay a different rate. Gas delivery customers have electricity, oil and propane as alternatives, and steam customers have electricity, oil and natural gas as alternative sources for heating and cooling their buildings. Micro-grids and community-based micro-grids enable DG to serve multiple locations and multiple customers. Demand reduction and energy efficiency investments provide ways for energy consumers within the Utilities’ service areas to lower their energy usage. The Companies expect DERs and electric alternatives to gas and steam, to increase, and for gas and steam usage to decrease, as the Climate Leadership and Community Protection Act enacted by New York State and the Climate Mobilization Act enacted by New York City in 2019 continue to be implemented. See “Environmental Matters – Clean Energy Future,” below. CECONY’s smart solutions for gas customers include energy efficiency and heating electrification programs. See “CECONY- Gas Operations - Gas Peak Demand,” below. The following table shows the aggregate capacities of the DG projects connected to the Utilities’ distribution systems at the end of the last five years:

20 CON EDISON ANNUAL REPORT 2020

Technology	CECONY					O&R
Total MW, except project number	2016	2017	2018	2019	2020	2016	2017	2018	2019	2020
Internal-combustion engines	104	108	110	114	129	2	2	2	3	3
Photovoltaic solar	135	178	226	276	323	63	75	96	121	154
Battery energy storage	—	—	—	8	13	—	—	—	1	6
Gas turbines	40	48	48	48	53	20	20	20	20	20
Micro turbines	10	14	17	18	21	1	1	1	1	1
Fuel cells	9	12	13	20	30	—	—	—	—	—
Steam turbines	4	6	6	6	6	—	—	—	—	—
Landfill	—	—	—	—	—	2	2	2	2	2
Total distribution-level DG	302	366	420	490	575	88	100	121	148	186
Number of DG projects	12,928	18,090	23,942	30,539	36,194	5,409	6,537	7,566	8,687	9,643

The Clean Energy Businesses participate in competitive renewable and sustainable energy infrastructure projects and provide energy-related products and services that are subject to different risks than those found in the businesses of the Utilities. See "Clean Energy Businesses," below. Con Edison Transmission invests in electric transmission facilities and holds investments in gas pipeline and storage facilities, the current and prospective customers of which may have competitive alternatives. See "Con Edison Transmission," below.

The Utilities do not consider it reasonably likely that another company would be authorized to provide utility delivery service of electricity, natural gas or steam where the company already provides service. Any such other company would need to obtain NYSPSC consent, satisfy applicable local requirements, install facilities to provide the service, meet applicable services standards and charge customers comparable taxes and other fees and costs imposed on the service. A new delivery company would also be subject to extensive ongoing regulation by the NYSPSC. See “Utility Regulation – State Utility Regulation – Regulators,” above, "The Companies Are Extensively Regulated And Are Subject To Substantial Penalties" in Item 1A and “Other Regulatory Matters” in Note B to the financial statements in Item 8.

The Utilities

CECONY

CECONY, incorporated in New York State in 1884, is a subsidiary of Con Edison and has no significant subsidiaries of its own. Its principal business segments are its regulated electric, gas and steam businesses.

For a discussion of the company’s operating revenues and operating income for each segment, see “Results of Operations” in Item 7. For additional information about the segments, see Note O to the financial statements in Item 8.

Electric Operations

Electric Facilities

CECONY’s capitalized costs for utility plant, net of accumulated depreciation, for distribution facilities were $20,366 million and $19,602 million at December 31, 2020 and 2019, respectively. For its transmission facilities, the costs for utility plant, net of accumulated depreciation, were $3,496 million and $3,380 million at December 31, 2020 and 2019, respectively, and for its portion of the steam-electric generation facilities, the costs for utility plant, net of accumulated depreciation, were $572 million and $591 million, at December 31, 2020 and 2019, respectively. See "CECONY – Steam Operations – Steam Facilities," below.

Distribution Facilities

CECONY owns 62 area distribution substations and various distribution facilities located throughout New York City and Westchester County. At December 31, 2020, the company’s distribution system had a transformer capacity of 33,027 MVA, with 37,119 miles of overhead distribution lines and 98,404 miles of underground distribution lines. The underground distribution lines represent the single longest underground electric delivery system in the United States.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 21

Transmission Facilities

CECONY’s transmission facilities are located in New York City and Westchester, Orange, Rockland, Putnam and Dutchess counties in New York State. At December 31, 2020, the company owned or jointly owned 569 miles of overhead circuits operating at 138, 230, 345 and 500 kV and 755 miles of underground circuits operating at 69, 138 and 345 kV. The company’s 40 transmission substations and 62 area stations are supplied by circuits operated at 69 kV and above. For information about transmission projects to address, among other things, reliability concerns associated with the scheduled closure of the Indian Point Energy Center (which is owned by Entergy Corporation subsidiaries) see “CECONY – Electric Operations – Electric Supply” and “Con Edison Transmission,” below. CECONY’s transmission facilities interconnect with those of National Grid, Central Hudson Gas & Electric Corporation, O&R, New York State Electric & Gas, Connecticut Light & Power Company, Long Island Power Authority, NYPA and Public Service Electric and Gas Company.

Generating Facilities 

CECONY’s electric generating facilities consist of plants located in Manhattan whose primary purpose is to produce steam for the company's steam business. The facilities have an aggregate capacity of 679 MW. The company expects to have sufficient amounts of gas and fuel oil available in 2021 for use in these facilities.

Electric Sales and Deliveries

CECONY delivers electricity to its full-service customers who purchase electricity from the company. The company also delivers electricity to its customers who choose to purchase electricity from other suppliers (retail choice program). In addition, the company delivers electricity to state and municipal customers of NYPA.

The company charges all customers in its service area for the delivery of electricity. The company generally recovers, on a current basis, the cost of the electricity that it buys and then sells to its full-service customers. It does not make any margin or profit on the electricity it sells. CECONY’s electric revenues are subject to a revenue decoupling mechanism. As a result, its electric delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. CECONY’s electric sales and deliveries for the last five years were:

	Year Ended December 31,
	2016	2017	2018	2019	2020
Electric Energy Delivered (millions of kWh)
CECONY full service customers	19,886	19,227	20,452	20,579	20,544
Delivery service for retail choice customers	26,813	26,136	26,266	24,754	22,000
Delivery service to NYPA customers and others	10,046	9,955	10,119	9,821	9,027
Total Deliveries in Franchise Area	56,745	55,318	56,837	55,154	51,571
Electric Energy Delivered ($ in millions)
CECONY full service customers	$4,404	$4,348	$4,706	$4,535	$4,804
Delivery service for retail choice customers	2,768	2,712	2,624	2,470	2,391
Delivery service to NYPA customers and others	610	623	652	644	638
Other operating revenues	324	289	(11)	413	270
Total Deliveries in Franchise Area	$8,106	$7,972	$7,971	$8,062	$8,103
Average Revenue per kWh Sold (Cents)
Residential	24.9	25.3	26.4	25.3	26.1
Commercial and industrial	19.1	19.7	19.3	18.6	20.2

For further discussion of the company’s electric operating revenues and its electric results, see “Results of Operations” in Item 7. For additional segment information, see Note O to the financial statements in Item 8.

Electric Peak Demand

The electric peak demand in CECONY’s service area occurs during the summer air conditioning season. The weather during the summer of 2020 was cooler than design weather conditions. CECONY’s 2020 service area actual hourly peak demand was 11,740 MW, which occurred on July 28, 2020. “Design weather conditions” for the electric system is a standard to which the actual hourly peak demand is adjusted for evaluation and planning purposes. Since NYISO-invoked demand reduction programs can only be called upon under specific circumstances, design weather conditions do not include these programs’ potential impact. However, the CECONY forecasted hourly peak demand at design conditions does include the impact of certain demand reduction programs. The

22 CON EDISON ANNUAL REPORT 2020

company estimates that, under design weather conditions, the 2021 service area hourly peak demand will be 12,880 MW. As of January 2021, the company forecasts an average annual increase in hourly electric peak demand in its service area at design weather conditions over the next five years to be approximately 0.8 percent per year, including the effect of certain electric energy efficiency programs. The five-year forecast in peak demand is used by the company for electric supply planning purposes.

Electric Supply

Most of the electricity sold by CECONY to its full-service customers in 2020 was purchased under firm power contracts or through the wholesale electricity market administered by the NYISO. The company expects that these resources will again be adequate to meet the requirements of its customers in 2021. The company plans to meet its continuing obligation to supply electricity to its customers through a combination of electricity purchased under contracts, purchased through the NYISO’s wholesale electricity market, or generated from its electricity generating facilities. For information about the company’s contracts for electric generating capacity, see Notes I and P to the financial statements in Item 8. To reduce the volatility of its customers’ electric energy costs, the company has contracts to purchase electric energy and enters into derivative transactions to hedge the costs of a portion of its expected purchases under these contracts and through the NYISO’s wholesale electricity market.

CECONY owns generating stations in New York City associated primarily with its steam system. As of December 31, 2020, the generating stations had a combined electric capacity of approximately 679 MW, based on 2020 summer test ratings. For information about electric generating capacity owned by the company, see “Electric Operations – Electric Facilities – Generating Facilities,” above.

In general, the Utilities recover their costs of purchasing power for full service customers, including the cost of hedging purchase prices, pursuant to rate provisions approved by the state public utility regulatory authority having jurisdiction. See “Financial and Commodity Market Risks – Commodity Price Risk” in Item 7 and “Recoverable Energy Costs” in Note A to the financial statements in Item 8.

CECONY monitors the adequacy of the electric capacity resources and related developments in its service area, and works with other parties on long-term resource adequacy within the framework of the NYISO reliability planning process. The NYISO process includes obligations on transmission owners (such as CECONY) to construct facilities that may be needed for system reliability if the market does not solve a reliability need identified by the NYISO. See “New York Independent System Operator,” above. In a July 1998 order, the NYSPSC indicated that it “agree(s) generally that CECONY need not plan on constructing new generation as the competitive market develops,” but considers “overly broad” and did not adopt CECONY’s request for a declaration that, solely with respect to providing generating capacity, it will no longer be required to engage in long-range planning to meet potential demand and, in particular, that it will no longer have the obligation to construct new generating facilities, regardless of the market price of capacity.

In April 2020, one of the two nuclear reactors at the Indian Point Energy Center (which is owned by Entergy Corporation subsidiaries) was shut down, while the other is scheduled to be closed in April 2021. The NYISO indicated that these retirements would not cause a reliability need if three units finalize construction and enter service. All three of the units have been placed into service. Two of the units, Bayonne Energy Center II Uprate (Zone J, 120 MW) and CPV Valley Energy Center (Zone G, 678 MW) entered service in 2018 (with the latter in litigation regarding its air permit) and the third unit, Cricket Valley Energy Center (Zone G, 1,020 MW), fully entered service in early 2020 before the retirement of the Indian Point unit.

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 to address the local transmission system reliability needs and expects to submit a plan to the NYISO to address the bulk transmission system reliability needs in the first half of 2021. The local transmission projects were also submitted to the NYSPSC in November 2020 as part of the New York utilities’ Transmission and Distribution Investment Working Group Report, due to the benefits they provide towards meeting New York State’s clean energy goals. CECONY’s implementation of all or part of its plans will be dependent upon the availability of market solutions and/or NYISO’s selection of

                                                                                                                         CON EDISON ANNUAL REPORT 2020 23

regulated solutions proposed by others. CECONY estimates that the costs of implementing plans to solve the local reliability needs, if required, to be approximately $780 million over 4 years and is unable to estimate the amount to implement plans to solve the bulk reliability needs, if required. In December 2020, CECONY filed a petition with the NYSPSC to recover the potential costs to solve both requirements and expect such costs to be recovered, including a full rate of return, in rates from customers.

Gas Operations

Gas Facilities

CECONY’s capitalized costs for utility plant, net of accumulated depreciation, for gas facilities, which are primarily distribution facilities, were $8,522 million and $7,961 million at December 31, 2020 and 2019, respectively.

Natural gas is delivered by pipeline to CECONY at various points in or near its service territory and is distributed to customers by the company through an estimated 4,341 miles of mains and 377,490 service lines. The company owns a natural gas liquefaction facility and storage tank at its Astoria property in Queens, New York. The plant can store 1,062 MDt of which a maximum of about 240 MDt can be withdrawn per day. The company has about 1,226 MDt of additional natural gas storage capacity at a field in upstate New York, owned and operated by Honeoye Storage Corporation, a corporation 71.2 percent owned by CET Gas and 28.8 percent owned by CECONY.

Gas Sales and Deliveries

The company generally recovers the cost of the gas that it buys and then sells to its full-service customers. It does not make any margin or profit on the gas it sells. CECONY’s gas revenues are subject to a weather normalization clause and a revenue decoupling mechanism. As a result, its gas delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. CECONY’s gas sales and deliveries for the last five years were:

	Year Ended December 31,
	2016	2017	2018	2019	2020
Gas Delivered (MDt)
Firm sales
Full service	75,892	83,005	92,305	87,637	78,515
Firm transportation of customer-owned gas	68,442	71,353	82,472	81,710	76,614
Total Firm Sales	144,334	154,358	174,777	169,347	155,129
Interruptible sales (a)	8,957	7,553	7,351	9,903	8,482
Total Gas Delivered to CECONY Customers	153,291	161,911	182,128	179,250	163,611
Transportation of customer-owned gas
NYPA	43,101	37,033	34,079	39,643	41,577
Other (mainly generating plants and interruptible transportation)	109,000	83,117	93,346	72,712	70,537
Off-system sales	—	55	195	12	12
Total Sales	305,392	282,116	309,748	291,617	275,737
Gas Delivered ($ in millions)
Firm sales
Full service	$933	$1,136	$1,356	$1,327	$1,229
Firm transportation of customer-owned gas	426	524	595	593	649
Total Firm Sales	1,359	1,660	1,951	1,920	1,878
Interruptible sales	34	35	40	42	27
Total Gas Delivered to CECONY Customers	1,393	1,695	1,991	1,962	1,905
Transportation of customer-owned gas
NYPA	2	2	2	2	2
Other (mainly generating plants and interruptible transportation)	57	56	57	54	55
Off-system sales	—	—	—	—	—
Other operating revenues (mainly regulatory amortizations)	56	148	28	114	74
Total Sales	$1,508	$1,901	$2,078	$2,132	$2,036
Average Revenue per Dt Sold
Residential	$13.96	$15.35	$16.71	$17.33	$18.59
General	$9.47	$10.86	$11.31	$11.55	$10.77

(a)Includes 4,708, 3,816, 3,326, 5,484 and 3,510 MDt for 2016, 2017, 2018, 2019 and 2020, respectively, which are also reflected in firm transportation and other.

24 CON EDISON ANNUAL REPORT 2020

For further discussion of the company’s gas operating revenues and its gas results, see “Results of Operations” in Item 7. For additional segment information, see Note O to the financial statements in Item 8.

Gas Peak Demand

The gas actual peak day demand for firm sales customers in CECONY’s service area occurs during the winter heating season and during the winter of 2020/2021 (through January 31, 2021) occurred on January 29, 2021 when the firm sales customers' demand reached approximately 1,209 MDt. “Design weather conditions” for the gas system is a standard to which the actual peak demand is adjusted for evaluation and planning purposes. The company estimates that, under design weather conditions, the 2021/2022 service area peak day demand for firm sales customers will be 1,692 MDt. The forecasted peak day demand for firm sales customers at design conditions does not include gas used by interruptible gas customers including electric and steam generating stations. As of January 2021, the company forecasts an average annual growth of the gas peak day demand for firm sales customers over the next five years at design conditions to be approximately 1.4 percent in its service area, including the effect of certain gas energy efficiency programs and the temporary moratorium described below. The five-year forecast in peak demand is used by the company for gas supply planning purposes.

In March 2019, due to gas supply constraints, CECONY established a temporary moratorium on new applications for firm gas service in most of Westchester County. In July 2020, CECONY filed a gas planning analysis with the NYSPSC that stated the moratorium could be lifted when increased pipeline capacity is achieved upon completion of the Tennessee pipeline’s 300L East project or peak demand is reduced through efficiency and other demand side reductions to a level that would enable the company to lift the moratorium. Assuming timely regulatory approvals, the Tennessee pipeline project is expected to be completed by November 2023. CECONY's gas planning analysis also stated that the company is monitoring gas supply constraint in the New York City portion of its service territory.

Gas Supply

CECONY and O&R have combined their gas requirements, and contracts to meet those requirements, into a single portfolio. The combined portfolio is administered by, and related management services are provided by, CECONY (for itself and as agent for O&R) and costs are allocated between the Utilities in accordance with provisions approved by the NYSPSC. See Note T to the financial statements in Item 8.

Charges from suppliers for the firm purchase of gas, which are based on formulas or indexes or are subject to negotiation, are generally designed to approximate market prices. The Utilities have contracts with interstate pipeline companies for the purchase of firm transportation from upstream points where gas has been purchased to the Utilities’ distribution systems, and for upstream storage services. Charges under these transportation and storage contracts are approved by the FERC. The Utilities are required to pay certain fixed charges under the supply, transportation and storage contracts whether or not the contracted capacity is actually used. These fixed charges amounted to approximately $347 million in 2020, including $307 million for CECONY. See “Contractual Obligations,” below. At December 31, 2020, the contracts were for various terms extending to 2025 for supply and 2043 for transportation and storage. During 2020, CECONY entered into three new transportation and storage contracts. In addition, the Utilities purchase gas on the spot market and contract for interruptible gas transportation. See “Recoverable Energy Costs” in Note A, Note Q and Note T to the financial statements in Item 8.

Steam Operations

Steam Facilities

CECONY’s capitalized costs for utility plant, net of accumulated depreciation, for steam facilities, including steam's portion of the steam-electric generation facilities, were $1,854 million and $1,813 million at December 31, 2020 and 2019, respectively. See "CECONY – Electric Operations – Electric Facilities," above.

CECONY generates steam at one steam-electric generating station and four steam-only generating stations and distributes steam to its customers through approximately 104 miles of transmission, distribution and service piping.

Steam Sales and Deliveries

                                                                                                                         CON EDISON ANNUAL REPORT 2020 25

CECONY’s steam sales and deliveries for the last five years were:

	Year Ended December 31,
	2016	2017	2018	2019	2020
Steam Sold (MMlb)
General	465	490	593	536	445
Apartment house	5,792	5,754	6,358	5,919	5,131
Annual power	13,722	13,166	14,811	13,340	10,977
Total Steam Delivered to CECONY Customers	19,979	19,410	21,762	19,795	16,553
Steam Sold ($ in millions)
General	$23	$26	$30	$27	$23
Apartment house	148	158	174	160	136
Annual power	378	392	441	395	321
Other operating revenues	2	19	(14)	45	28
Total Steam Delivered to CECONY Customers	$551	$595	$631	$627	$508
Average Revenue per Mlb Sold	$27.48	$29.68	$29.64	$29.40	$29.00

For further discussion of the company’s steam operating revenues and its steam results, see “Results of Operations” in Item 7. For additional segment information, see Note O to the financial statements in Item 8.

Steam Peak Demand and Capacity

The steam actual hourly peak demand in CECONY’s service area occurs during the winter heating season and during the winter of 2020/2021 (through January 31, 2021) occurred on January 29, 2021 when the actual hourly demand reached approximately 7.0 MMlb per hour. “Design weather conditions” for the steam system is a standard to which the actual hourly peak demand is adjusted for evaluation and planning purposes. The company’s estimate for the winter of 2021/2022 hourly peak demand of its steam customers is about 8.4 MMlb per hour under design weather conditions. As of January 2021, the company forecasts an average annual decrease in steam hourly peak demand in its service area at design weather conditions over the next five years to be approximately 0.4 percent. The five year forecast in peak demand is used by the company for steam asset management purposes.

On December 31, 2020, the steam system was capable of delivering approximately 11.4 MMlb of steam per hour, and CECONY estimates that the system will have the same capability in the 2021/2022 winter.

Steam Supply

27 percent of the steam produced by CECONY in 2020 was supplied by the company’s steam-only generating assets; 53 percent was produced by the company’s steam-electric generating assets, where steam and electricity are primarily cogenerated; and 20 percent was purchased under an agreement with Brooklyn Navy Yard Cogeneration Partners L.P.

O&R

Electric Operations

Electric Facilities

O&R’s capitalized costs for utility plant, net of accumulated depreciation, for distribution facilities were $1,115 million and $1,074 million at December 31, 2020 and 2019, respectively. For its transmission facilities, the costs for utility plant, net of accumulated depreciation, were $290 million and $254 million at December 31, 2020 and 2019, respectively.

O&R and RECO own, in whole or in part, transmission and distribution facilities which include 533 circuit miles of transmission lines, 15 transmission substations, 64 distribution substations, 89,673 in-service line transformers, 3,729 pole miles of overhead distribution lines and 2,210 miles of underground distribution lines. O&R’s transmission system is part of the NYISO system except that portions of RECO’s system are located within the transmission area controlled by PJM.

Electric Sales and Deliveries

O&R delivers electricity to its full-service customers who purchase electricity from the company. The company also delivers electricity to its customers who purchase electricity from other suppliers through the company’s retail choice program.

The company charges all customers in its service area for the delivery of electricity. O&R generally recovers, on a current basis, the cost of the electricity that it buys and then sells to its full-service customers. It does not make any

26 CON EDISON ANNUAL REPORT 2020

margin or profit on the electricity it sells. O&R’s New York electric revenues (which accounted for 75 percent of O&R’s electric revenues in 2020) are subject to a revenue decoupling mechanism. As a result, O&R’s New York electric 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. O&R’s electric sales and deliveries for the last five years were:

	Year Ended December 31,
	2016	2017	2018	2019	2020
Electric Energy Delivered (millions of kWh)
Total deliveries to O&R full service customers	2,555	2,435	2,643	2,617	2,712
Delivery service for retail choice customers	3,180	2,976	2,974	2,885	2,622
Total Deliveries in Franchise Area	5,735	5,411	5,617	5,502	5,334
Electric Energy Delivered ($ in millions)
Total deliveries to O&R full service customers	$426	$433	$453	$429	$442
Delivery service for retail choice customers	213	201	201	191	186
Other operating revenues	(2)	8	(12)	14	1
Total Deliveries in Franchise Area	$637	$642	$642	$634	$629
Average Revenue Per kWh Sold (Cents)
Residential	18.4	19.8	19.1	18.2	17.8
Commercial and Industrial	14.3	15.0	14.4	13.9	14.2

For further discussion of the company’s electric operating revenues and its electric results, see “Results of Operations” in Item 7. For additional segment information, see Note O to the financial statements in Item 8.

Electric Peak Demand

The electric peak demand in O&R’s service area occurs during the summer air conditioning season. The weather during the summer of 2020 was cooler than design conditions. O&R’s 2020 service area actual hourly peak demand was 1,430 MW, which occurred on July 27, 2020. “Design weather” for the electric system is a standard to which the actual hourly peak demand is adjusted for evaluation and planning purposes. Since NYISO-invoked demand reduction programs can only be called upon under specific circumstances, design weather conditions do not include these programs’ potential impact. However, the O&R forecasted hourly peak demand at design conditions does include the impact of certain demand reduction programs. The company estimates that, under design weather conditions, the 2021 service area peak demand will be 1,530 MW. The company forecasts an average annual decrease in hourly electric peak demand in its service area at design conditions over the next five years to be approximately 0.5 percent, including the effect of certain electric energy efficiency programs. The five-year forecast in peak demand is used by the company for electric supply planning purposes.

Electric Supply

The electricity O&R sold to its full-service customers in 2020 was purchased under firm power contracts or through the wholesale electricity market. The company expects that these resources will again be adequate to meet the requirements of its customers in 2021. O&R does not own any electric generating capacity. The company plans to meet its continuing obligation to supply electricity to its customers through a combination of electricity purchased under contracts or purchased through the wholesale electricity market. To reduce the volatility of its customers’ electric energy costs, the company has contracts to purchase electric energy and enters into derivative transactions to hedge the costs of a portion of its expected purchases. For information about the company’s contracts, see Note P to the financial statements in Item 8.

In general, the Utilities recover their costs of purchasing power for full service customers, including the cost of hedging purchase prices, pursuant to rate provisions approved by the state public utility regulatory authority having jurisdiction. See “Financial and Commodity Market Risks – Commodity Price Risk,” in Item 7 and “Recoverable Energy Costs” in Note A to the financial statements in Item 8. From time to time, certain parties have petitioned the NYSPSC to review these provisions, the elimination of which could have a material adverse effect on the Companies’ financial position, results of operations or liquidity.

Gas Operations

Gas Facilities

O&R’s capitalized costs for utility plant, net of accumulated depreciation for gas facilities, which are primarily distribution facilities, were $684 million and $656 million at December 31, 2020 and 2019, respectively. Natural gas

                                                                                                                         CON EDISON ANNUAL REPORT 2020 27

is delivered by pipeline to O&R at various points in or near its service territory and is distributed to customers by the company through an estimated 1,879 miles of mains and 106,701 service lines.

Gas Sales and Deliveries

O&R generally recovers the cost of the gas that it buys and then sells to its full-service customers. It does not make any margin or profit on the gas it sells. O&R’s gas revenues are subject to a weather normalization clause and to a revenue decoupling mechanism. As a result, its gas delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. O&R’s gas sales and deliveries for the last five years were:

	Year Ended December 31,
	2016	2017	2018	2019	2020
Gas Delivered (MDt)
Firm sales
Full service	9,723	10,480	12,050	12,537	11,877
Firm transportation	10,381	9,873	9,950	9,459	8,271
Total Firm Sales	20,104	20,353	22,000	21,996	20,148
Interruptible sales	3,853	3,771	3,746	3,668	3,633
Total Gas Delivered to O&R Customers	23,957	24,124	25,746	25,664	23,781
Transportation of customer-owned gas
Sales for resale	867	896	959	914	658
Sales to electric generating stations	18	9	1	4	59
Off-system sales	16	6	15	1	19
Total Sales	24,858	25,035	26,721	26,583	24,517

	Year Ended December 31,
	2016	2017	2018	2019	2020
Gas Delivered ($ in millions)
Firm sales
Full service	$99	$139	$166	$161	$141
Firm transportation	70	74	78	63	62
Total Firm Sales	169	213	244	224	203
Interruptible Sales	3	7	6	6	6
Total Gas Delivered to O&R Customers	172	220	250	230	209
Transportation of customer-owned gas
Sales to electric generating stations	—	—	—	—	—
Other operating revenues	12	12	(1)	29	24
Total Sales	$184	$232	$249	$259	$233
Average Revenue Per Dt Sold
Residential	$10.71	$13.86	$14.22	$13.32	$12.40
General	$8.17	$11.08	$11.80	$10.68	$9.51

For further discussion of the company’s gas operating revenues and its gas results, see “Results of Operations” in Item 7. For additional segment information, see Note O to the financial statements in Item 8.

Gas Peak Demand

The gas actual peak day demand for firm sales customers in O&R’s service area occurs during the winter heating season and during the winter of 2020/2021 (through January 31, 2021) occurred on January 29, 2021 when the firm sales customers' demand reached approximately 181 MDt. “Design Weather” for the gas system is a standard to which the actual peak demand is adjusted for evaluation and planning purposes. The company estimates that, under design weather conditions, the 2021/2022 service area peak day demand for firm sales customers will be 232 MDt. The forecasted peak day demand at design conditions does not include gas used by interruptible gas customers including electric generating stations. The company forecasts an average annual growth of the gas peak day demand for firm sales customers over the next five years at design conditions to be approximately 0.2 percent in its service area, including the effect of certain gas energy efficiency programs. The five-year forecast in peak demand is used by the company for gas supply planning purposes.

28 CON EDISON ANNUAL REPORT 2020

Gas Supply

O&R and CECONY have combined their gas requirements and purchase contracts to meet those requirements into a single portfolio. See “CECONY – Gas Operations – Gas Supply” above.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 29

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 December 31, 2020:

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
Crane Solar	150	12	2020	Texas	Vistra
Other	26	Various	Various	Various	Various
Total Solar	2,395
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
Coram Wind (e)	102	16	2016	California	PG&E
Other	34	Various	Various	Various	Various
Total Wind	414
Total MW (AC) in Operation	2,809
Total MW (AC) in Construction (g)	431
Total MW (AC) Utility Scale	3,240
Behind the Meter
Total MW (AC) in Operation	59
Total MW (AC) in Construction	11
Total MW Behind the Meter	70

(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: 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) and NorthWestern Energy (NWE). For information about PG&E’s bankruptcy, see “Long-Lived and Intangible Assets” in Note A to the financial statements in Item 8.

(d)Solar renewable energy credit hedges are in place, in lieu of power purchase agreements, through 2024.

(e)Project has been pledged as security for project debt financing. See Con Edison's Consolidated Statement of Capitalization in Item 8.

(f)Projects are financed with tax equity. See Note R to the financial statements in Item 8.

(g)Projects in construction are being financed under a variable-rate construction loan facility that matures no later than November 2021. See Note D to the financial statements in Item 8.

30 CON EDISON ANNUAL REPORT 2020

Renewable Electric Generation

The Clean Energy Businesses develop, own and operate renewable and sustainable energy infrastructure projects. In December 2018, the Clean Energy Businesses acquired Sempra Solar Holdings, LLC to expand the company's renewable energy asset portfolio. See Note V to the financial statements in Item 8. The Clean Energy Businesses focus their efforts on utility scale renewable electric production projects. The output of most of the projects is sold under long-term power purchase agreements (PPA) with utilities and municipalities. The following table shows the generating capacity (MW AC) of the Clean Energy Businesses' utility scale renewable electric production projects in operation at the end of the last five years:

Generating Capacity (MW AC)	2016	2017	2018	2019	2020
Renewable electric production projects	1,098	1,358	2,588	2,628	2,809

Renewable electric volumes produced by utility scale assets for the years ended December 31, 2017, 2018, 2019, and 2020 were:

		Millions of kWh Produced
		For the Years Ended December 31,
Description	2017	2018	2019	2020
Renewable electric production projects
Solar	2,158	2,680	5,506	5,699
Wind	988	1,074	1,333	1,425
Total	3,146	3,754	6,839	7,124

                                                                                                                         CON EDISON ANNUAL REPORT 2020 31

Energy-Related Products and Services

The Clean Energy Businesses provide services to manage the dispatch, fuel requirements and risk management activities for 11,114 MW of generating plants and merchant transmission in the northeastern United States owned by unrelated parties, manage energy supply assets leased from others and provide wholesale hedging and risk management services to renewable electric production projects owned by their subsidiaries.

The Clean Energy Businesses also provide energy-efficiency services to government and commercial customers. The services include the design and installation of lighting retrofits, high-efficiency heating, ventilating and air conditioning equipment and other energy saving technologies.

For information about the Clean Energy Businesses' results, see "Results of Operations" in Item 7 and Note O to the financial statements in Item 8.

Con Edison Transmission

CET Electric

CET Electric owns a 45.7 percent interest in New York Transco LLC (NY Transco). Affiliates of certain other New York transmission owners own the remaining interests.

NY Transco's Transmission Owner Transmission Solutions (TOTS) projects were approved by the NYSPSC in October 2013 in its proceeding to address potential needs that could arise should the Indian Point Energy Center (which is owned by Entergy Corporation subsidiaries) no longer operate. See “CECONY - Electric Operations - Electric Supply,” above.

In April 2015, the FERC issued an order granting certain transmission incentives for the NY Transco TOTS projects. In March 2016, the FERC approved a November 2015 settlement agreement that provides, in relation to the TOTS projects described above, a 10 percent return on common equity (which is comprised of 9.5 percent base return on equity plus an additional 50 basis points) and a maximum actual common equity ratio of 53 percent. The revenues for these TOTS projects costs are collected by the NYISO and allocated across New York State, with 63 percent allocated to load serving entities in the CECONY and O&R service areas.

In December 2015, the NYSPSC issued an order in its competitive proceeding to select AC transmission projects that would relieve transmission congestion between upstate and downstate. The NYSPSC determined that there was a public policy need for new transmission to address congestion and directed the NYISO, under its FERC-approved public policy planning process, to request developers to submit transmission project proposals for two segments of the transmission system. In April 2019, the New York Independent System Operator (NYISO) selected a project that was jointly proposed by National Grid and NY Transco ($600 million estimated cost, excluding certain interconnection costs that are not yet determined) that would increase transmission capacity by 1,850 MW between upstate and downstate when combined with another developer’s project that was also selected by the NYISO. The siting, construction and operation of the projects will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO and National Grid/NY Transco entered into an agreement for the development and operation of the project, referred to as the New York Energy Solution (NYES) project, that is scheduled for entry into service by December 2023.  In November 2017, FERC approved a settlement agreement with respect to the National Grid/NY Transco project that provides for a 10.65 percent return on common equity (which is comprised of a 9.65 percent base ROE, with 100 basis points added for congestion reduction and a cost containment mechanism applicable to certain capital costs) and a maximum actual common equity ratio of 53 percent. Revenues for the NYES project are collected by the NYISO including 100 percent of construction work-in-progress, and are allocated across New York State with 84 percent allocated to load serving entities in the CECONY and O&R service areas.

CET Gas

CET Gas, through its subsidiaries, owns a 50 percent interest in Stagecoach Gas Services LLC (Stagecoach), a 71.2 percent interest in Honeoye Storage Corporation (Honeoye) and an interest, described below, in Mountain Valley Pipeline LLC (MVP).

Stagecoach is a joint venture with a subsidiary of Crestwood Equity Partners LP (Crestwood) to own, operate and further develop a gas pipeline and storage business located in northern Pennsylvania and southern New York. Stagecoach provides services to its customers (including CECONY, see Note T to the financial statements in Item 8) through its 181 miles of pipe and 41 Bcf of storage capacity. Con Edison is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC. Honeoye, in which CECONY owns the remaining interest, operates a gas storage facility in upstate New York.

32 CON EDISON ANNUAL REPORT 2020

MVP is a joint venture with four other partners to construct and operate a proposed 300-mile gas transmission project in West Virginia and Virginia. CET Gas owns an 11.3 percent interest in the joint venture, that is expected to be reduced to 8.8 percent based on the current project cost estimate and CET Gas’ previous capping of its cash contributions to the joint venture. CET Gas recorded a pre-tax impairment loss of $320 million ($223 million after-tax) for the year ended December 31, 2020 that reduced the carrying value of its investment in MVP from $662 million to $342 million. See "Investments - Partial Impairment of Investment in Mountain Valley Pipeline" in Note A to the financial statements in Item 8

For information about Con Edison Transmission's results, see "Results of Operations" in Item 7 and Note O to the financial statements in Item 8.

Capital Requirements and Resources

Capital Requirements

The following table contains the Companies’ capital requirements for the years 2018 through 2020 and their current estimate of amounts for 2021 through 2023:

	Actual			Estimate
(Millions of Dollars)	2018	2019	2020	2021	2022	2023
CECONY (a)(b)
Electric	$1,861	$1,851	$2,080	$2,284	$2,106	$2,307
Gas	1,050	1,078	1,044	1,126	1,014	1,056
Steam	94	91	122	100	91	94
Sub-total	3,005	3,020	3,246	3,510	3,211	3,457
O&R
Electric	138	142	159	150	184	187
Gas	67	61	61	61	83	80
Sub-total	205	203	220	211	267	267
Con Edison Transmission
CET Electric	—	8	2	46	65	47
CET Gas	248	197	1	1	—	—
Sub-total	248	205	3	47	65	47
Clean Energy Businesses	1,791	248	616	250	400	400
Total capital expenditures	5,249	3,676	4,085	4,018	3,943	4,171
Retirement of long-term securities
Con Edison – parent company	2	553	3	1,178	293	650
CECONY	1,836	475	350	640	—	—
O&R	55	62	—	—	—	—
Clean Energy Businesses	45	105	165	149	144	316
Total retirement of long-term securities	1,938	1,195	518	1,967	437	966
Total capital requirements	$7,187	$4,871	$4,603	$5,985	$4,380	$5,137

(a)CECONY’s capital expenditures for environmental protection facilities and related studies were $490 million, $507 million and $491 million in 2018, 2019 and 2020, respectively, and are estimated to be $674 million in 2021.

(b)Amounts shown do not include amounts for the energy efficiency, demand reduction and combined heat and power programs.

The Utilities have an ongoing need to make substantial capital investments primarily to maintain the reliability of their electric, gas and steam delivery systems. Their estimated construction expenditures also reflect programs that will give customers greater control over their energy usage and bills, help integrate customers' new clean energy technologies into the Utilities’ electric delivery systems and accelerate the replacement of leak-prone gas distribution mains and service lines.

Estimated capital expenditures for Con Edison Transmission primarily reflect planned investments in electric transmission projects. Estimated capital expenditures for the Clean Energy Businesses primarily reflect planned investments in renewable electric production projects. Actual capital expenditures for Con Edison Transmission and the Clean Energy Businesses could increase or decrease significantly from the amounts estimated depending on opportunities.

Contractual Obligations

The following table summarizes the Companies’ material obligations at December 31, 2020 to make payments pursuant to contracts. Long-term debt, capital lease obligations and other noncurrent liabilities are included on their

                                                                                                                         CON EDISON ANNUAL REPORT 2020 33

balance sheets. Operating leases and electricity purchase agreements (for which undiscounted future annual payments are shown) are described in the notes to the financial statements.

	Payments Due by Period
(Millions of Dollars)	Total	1 year or less	Years 2 & 3	Years 4 & 5	After 5 years
Long-term debt (Statement of Capitalization)
CECONY	$16,965	$640	—	$250	$16,075
O&R	900	—	—	—	900
Clean Energy Businesses	2,578	149	460	450	1,519
Parent	2,121	1,178	943	—	—
Interest on long-term debt (a)	17,826	879	1,693	1,629	13,625
Total long-term debt, including interest	40,390	2,846	3,096	2,329	32,119
Finance lease obligations (Note J)
CECONY	2	1	1	—	—
O&R	1	—	—	—	1
Total capital lease obligations	3	1	1	—	1
Operating leases (Note J)
CECONY	743	62	115	115	451
O&R	2	1	1	—	—
Clean Energy Businesses	573	16	35	35	487
Total operating leases	1,318	79	151	150	938
Purchase obligations
Electricity power purchase agreements – Utilities (Note I)
CECONY
Energy	1,609	92	184	186	1,147
Capacity (b)	906	138	174	107	487
Total CECONY	2,515	230	358	293	1,634
O&R
Energy and Capacity (b)	119	63	56	—	—
Total electricity and power purchase agreements – Utilities	2,634	293	414	293	1,634
Natural gas supply, transportation, and storage contracts – Utilities (c)
CECONY
Natural gas supply	210	144	64	2	—
Transportation and storage	4,556	399	759	542	2,856
Total CECONY	4,766	543	823	544	2,856
O&R
Natural gas supply	26	16	10	—	—
Transportation and storage	683	59	112	80	432
Total O&R	709	75	122	80	432
Total natural gas supply, transportation and storage contracts	5,475	618	945	624	3,288
Other purchase obligations
CECONY (d)	6,224	1,109	1,896	1,332	1,887
O&R (d)	246	43	145	51	7
Clean Energy Businesses (e)	164	106	35	12	11
Total other purchase obligations	6,634	1,258	2,076	1,395	1,905
Total	$56,454	$5,095	$6,683	$4,791	$39,885

(a)Includes interest on variable rate debt calculated at rates in effect at December 31, 2020.

(b)Included in these amounts is the cost of minimum quantities of energy that the Utilities are obligated to purchase at both fixed and variable prices.

(c)Included in these amounts is the cost of minimum quantities of natural gas supply, transportation and storage that the Utilities are obligated to purchase at both fixed and variable prices.

(d)Amounts shown for other purchase obligations, which reflect capital and operations and maintenance costs incurred by the Utilities in running their day-to-day operations, were derived from the Utilities’ purchasing system as the difference between the amounts authorized and the amounts paid (or vouchered to be paid) for each obligation. For many of these obligations, the Utilities are committed to purchase less than the amount authorized. Payments for the “Other Purchase Obligations” are generally assumed to be made ratably over the term of the obligations. Long-term Purchase Obligations, which comprises $5,741 million of "Other Purchase Obligations," were derived from the Utilities' purchasing system by using a method that identifies the remaining purchase obligations. The Utilities believe that unreasonable effort and expense would be involved to enable them to report their “Other Purchase Obligations” in a different manner.

(e)Amounts represent commitments by the Clean Energy Businesses to purchase minimum quantities of electric energy and capacity, renewable energy certificates, natural gas, natural gas pipeline capacity, energy efficiency services and construction services. The Clean

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Energy Businesses have also entered into power purchase agreements for the sale of power from their renewable electric production projects, provisions of which provide for penalties to be paid by the Clean Energy Businesses in the event certain minimum production quantities are not met. The future minimum production quantities and the amount of the penalties, if any, are not estimable and are not included in the amounts shown on the table.

The Companies’ commitments to make payments in addition to these contractual commitments include their other liabilities reflected on their balance sheets, any funding obligations for their pension and other postretirement benefit plans, financial hedging activities, their collective bargaining agreements and Con Edison’s and the Clean Energy Business' guarantees of certain obligations. See Notes E, F, P and “Guarantees” in Note H to the financial statements in Item 8.

Capital Resources

Con Edison is a holding company that operates only through its subsidiaries and has no material assets other than its interests in its subsidiaries. Con Edison finances its capital requirements primarily through internally-generated funds, the sale of its common shares or external borrowings. Con Edison’s ability to make payments on external borrowings and dividends on its common shares depends on receipt of dividends from its subsidiaries, proceeds from the sale of additional common shares or its interests in its subsidiaries or additional external borrowings. See "Con Edison's Ability To Pay Dividends Or Interest Depends On Dividends From Its Subsidiaries" in Item 1A and Note T to the financial statements in Item 8.

For information about restrictions on the payment of dividends by the Utilities and significant debt covenants, see Note C to the financial statements in Item 8.

For information on the Companies’ commercial paper program, revolving credit agreements with banks and on Con Edison's term loan and the construction loan of a subsidiary of the Clean Energy Businesses, see Note D to the financial statements in Item 8.

The Companies require access to the capital markets to fund capital requirements that are substantially in excess of available internally-generated funds. See “Capital Requirements,” above and "The Companies Require Access To Capital Markets to Satisfy Funding Requirements” in Item 1A. Each of the Companies believes that it will continue to be able to access capital, although capital market conditions may affect the timing and cost of the Companies’ financing activities. The Companies monitor the availability and costs of various forms of capital, and will seek to issue Con Edison common stock and other securities when it is necessary or advantageous to do so. See “Coronavirus Disease 2019 (COVID-19) Impacts – Liquidity and Financing” in Item 7. For information about the Companies’ long-term debt and short-term borrowing, see Notes C and D to the financial statements in Item 8.

The Utilities finance their operations, capital requirements and payment of dividends to Con Edison from internally-generated funds, contributions of equity capital from Con Edison, if any, and external borrowings. See "Liquidity and Capital Resources" in Item 7.

Con Edison plans to meet its capital requirements for 2021 through 2023, through internally-generated funds and the issuance of long-term debt and common equity. See “Capital Requirements," above in Item 1. 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.

In 2019, the NYSPSC authorized CECONY, through 2022, to issue up to $5,600 million of debt securities ($3,500 million of which the company had issued as of December 31, 2020). In 2020, the NYSPSC authorized O&R, through 2023, to issue up to $165 million of debt securities ($75 million of which the company had issued as of December 31, 2020). The NYSPSC also authorized CECONY and O&R for such periods to issue debt securities to refund existing debt securities of up to $2,500 million and $125 million, respectively. As of December 31, 2020, the Utilities had not refunded any securities pursuant to these authorizations.

The Clean Energy Businesses have financed their operations and capital requirements primarily with capital contributions and borrowings from Con Edison, internally-generated funds and external borrowings. See Con Edison's Consolidated Statement of Capitalization in Item 8 and Note P to the financial statements in Item 8. In February 2021, a subsidiary of the Clean Energy Businesses borrowed $250 million at a variable-rate, due 2028,

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secured by equity interests in solar electric production projects. The company has entered into fixed-rate interest rate swaps in connection with this borrowing.

Con Edison Transmission has financed its operations and capital requirements primarily with capital contributions and borrowings from Con Edison and internally-generated funds. See "Liquidity and Capital Resources" in Item 7.

For each of the Companies, the common equity ratio for the last five years was:

	Common Equity Ratio (Percent of total capitalization)
	2016	2017	2018	2019	2020
Con Edison	49.3	51.1	49.0	49.6	48.3
CECONY	49.5	50.8	48.6	49.2	47.9

The credit ratings assigned by Moody’s, S&P and Fitch to the senior unsecured debt and commercial paper of Con Edison, CECONY and O&R are as follows:

	Moody's	S&P	Fitch
Con Edison
Senior Unsecured Debt	Baa2	BBB+	BBB+
Commercial Paper	P-2	A-2	F2
CECONY
Senior Unsecured Debt	Baa1	A-	A-
Commercial Paper	P-2	A-2	F2
O&R
Senior Unsecured Debt	Baa2	A-	A-
Commercial Paper	P-2	A-2	F2

Credit ratings assigned by rating organizations are expressions of opinion and are not recommendations to buy, sell or hold securities. A credit rating is subject to revision or withdrawal at any time by the assigning rating organization. Each rating should be evaluated independently of any other rating. See “The Companies Require Access To Capital Markets To Satisfy Funding Requirements” and “Changes To Tax Laws Could Adversely Affect the Companies” in Item 1A.

In 2017, the United Kingdom’s Financial Conduct Authority announced that it intends to stop persuading or compelling banks to submit London Interbank Offered Rates (LIBOR) after 2021. In November 2020, LIBOR’s administrator announced it plans to consult on its intention to cease publication of one-week and two-month U.S. Dollar LIBOR immediately after the LIBOR publication on December 31, 2021, and the remaining U.S. Dollar LIBOR tenors immediately after publication on June 30, 2023.The Companies have been and are continuing to monitor LIBOR-related market, regulatory and accounting developments. The Companies’ material contracts that reference LIBOR and currently extend beyond 2021 include their $2,250 million credit agreement (see Note D to the financial statements in Item 8). Pursuant to the credit agreement, the Companies may borrow at interest rates determined with reference to a prime rate, the federal funds rate or LIBOR. The credit agreement may be amended by the Companies and the administrative agent to provide for a LIBOR successor rate unless a majority of the lenders do not accept the amendment. In addition, the Clean Energy Businesses have $999 million of variable rate project debt that reference LIBOR and currently extends beyond 2021 and that allows for an alternate reference rate and associated interest rate swaps with a notional amount of $863 million (see Note P to the financial statements in Item 8). Con Edison expects that, prior to the discontinuation of LIBOR, the Clean Energy Businesses will be able to agree with project lenders and swap counterparties on the use of an alternate reference rate as needed. The Companies do not expect that a discontinuation of LIBOR would have a material impact on their financial position, results of operations or liquidity. 

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Environmental Matters

Clean Energy Future

Climate Leadership and Community Protection Act

In 2019, New York State enacted the Climate Leadership and Community Protection Act (CLCPA) that established a goal of 70 percent of the electricity procured by load serving entities regulated by the NYSPSC to be produced by renewable energy systems by 2030 and requires the statewide electrical demand system to have zero emissions by 2040. The law also codified state targets for energy efficiency (end-use energy savings of 185 trillion British thermal units below 2025 energy-use forecast), offshore wind (9,000 megawatts (MW) by 2035), solar (6,000 MW by 2025) and energy storage (3,000 MW by 2030). In addition, the law established a climate action council to recommend measures to attain the law’s greenhouse gases (GHG) limits, including measures to reduce emissions by displacing fossil-fuel fired electricity with renewable electricity or by implementing energy efficiency measures. The climate action council is expected to release draft recommendations for public comment in 2022. The law also requires the consideration of electric transportation and electric heating to achieve its goals. As required by the law, the NYSDEC adopted regulations establishing statewide GHG emissions limits that are 60 percent of 1990 emissions levels by 2030 and 15 percent of 1990 emissions by 2050. The Utilities are unable to predict the impact on them of the implementation of this law.

In October 2020, the NYSPSC, in response to the CLCPA, modified its clean energy standard to establish a new renewable energy credits (RECs) program to support increased renewable energy availability in New York City for which the costs would be socialized statewide. CECONY and O&R have been required to obtain RECs and zero-emissions credits (ZECs) for their full service customers since 2017. Load serving entities may satisfy their RECs obligation by either purchasing RECs acquired through central procurement by the New York State Energy Research and Development Authority (NYSERDA), by self-supply through direct purchase of tradable RECs, or by making alternative compliance payments. Load serving entities purchase ZECs from NYSERDA at prices determined by the NYSPSC.

Prior to enactment of the CLCPA and its expansion of offshore wind goals, in July 2018, the NYSPSC established a goal of 2,400 MW of new offshore wind facilities by 2030. As a result of this goal, load-serving entities, such as CECONY and O&R, will be required to purchase offshore wind renewable energy credits (ORECs) from NYSERDA beginning in 2025 when projects are expected to begin operation. In October 2019, NYSERDA entered into a 25-year power purchase agreement (PPA) with Equinor Wind US LLC for its 816 MW Empire Wind Project, and a 25-year PPA with Sunrise Wind LLC for its 880 MW Sunrise Wind Project. In 2020, NYSERDA issued a new solicitation and provisionally awarded two contracts - one that would expand the Empire Wind Project to 1,260 MW and another to Equinor Wind US LLC for its 1,230 MW Beacon Wind Project.

In August 2019, following the enactment of the CLCPA, the NYSPSC initiated a proceeding to “reconcile resource adequacy programs with New York State’s renewable energy and environmental emission reduction goals.” See “New York Independent System Operator (NYISO),” above and “Climate Change,” below. In May 2020, the NYSPSC initiated a proceeding implementing the Accelerated Renewable Energy Growth and Community Benefit Act to align New York State’s electric system with CLCPA goals. In November 2020, New York’s investor-owned utilities (including the Utilities) and LIPA filed a comprehensive report in this proceeding, identifying proactive local transmission and distribution investments in their systems to achieve the goals of the CLCPA and setting out policy recommendations for how they will identify, prioritize and allocate costs of these and future such projects going forward. CECONY and O&R have identified approximately $4,500 million and $400 million, respectively, in local transmission investment.

Federal and local municipal laws and agencies also regulate emissions levels and impact the CLCPA’s decarbonization pathways. In 2015, the United States Environmental Protection Agency (EPA) issued its Clean Power Plan, which was repealed by the EPA in June 2019, and would have required states to reduce carbon dioxide emissions from existing power plants 32 percent from 2005 levels by 2030. Under the Clean Power Plan, each state would have been required to submit for EPA approval a plan to reduce its emissions to specified rate-based or equivalent mass-based target levels (as determined in accordance with the Clean Power Plan) applicable to the state. For New York State, the emissions rate-based target level for 2030 would have been approximately 20 percent below its 2012 emissions rate. State plans may, among other things, include participation in regional cap-and-trade programs. In June 2019, the EPA issued its Affordable Clean Energy (ACE) rule. The ACE rule establishes guidelines for states to use when developing plans to limit carbon dioxide emissions at coal-fired power plants and includes implementing regulations for future existing-source rules under the Clean Air Act. In September 2019, Con Edison, as part of a coalition of public and private electric utilities, filed a petition in the United States Court of Appeals for the District of Columbia Circuit to challenge the ACE rule and the repeal of the Clean Power Plan. The ACE rule could have potential cost implications for utilities because it has the effect of limiting flexibility to

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use measures such as emissions trading and averaging to cost-effectively meet emissions limits. The ACE rule could also adversely impact initiatives to develop renewable energy sources and promote the use of electric vehicles. In January 2021, the Court of Appeals vacated and remanded the ACE rule to the EPA on the grounds that the ACE Rule was based on a critically mistaken reading of the Clean Air Act. In its ruling, the court adopted the argument advanced by the utilities coalition that the Clean Air Act did not foreclose EPA flexibility to consider other measures, such as emissions trading, to reduce carbon dioxide emissions.

In 2014, New York City announced a goal to reduce GHG emissions 80 percent below 2005 levels by 2050. In May 2019, New York City enacted a package of legislation known as the Climate Mobilization Act, that includes provisions intended to reduce GHG emissions from large buildings by 40 percent from 2005 levels by 2030. Building owners may achieve compliance through operational changes, building retrofits, the purchase of greenhouse gas offsets, the purchase of renewable energy credits and the use of clean distributed energy resources. CECONY is unable to predict the impact on it of the implementation of this law.

Reforming the Energy Vision

In April 2014, the NYSPSC began a multi-year process --Reforming the Energy Vision (REV)-- to improve electric system efficiency and reliability, encourage renewable energy resources, support distributed energy resources (DER), and enable more customer choice. DER includes distributed generation (such as solar electric production facilities, fuel cells and micro-turbines), energy storage, demand reduction and energy efficiency programs. Following a broad assortment of early REV proceedings, implementation of REV has shifted to focus on integrating distributed generation and modifying ratemaking designs.

The NYSPSC is directing development by New York electric utilities of a distributed system platform to manage and coordinate DER in their service areas under NYSPSC regulation and to provide customers, together with third parties, with data and tools to better manage their energy use. The NYSPSC has required the Utilities to file distributed system implementation plans and ordered the Utilities to develop demonstration projects to inform distributed system platform business models. Through December 31, 2020, the NYSPSC staff has approved nine CECONY, three O&R, and one joint CECONY-O&R demonstration projects.

The NYSPSC approved CECONY’s advanced metering infrastructure (AMI) installation plan for its electric and gas delivery businesses, subject to a cap on capital expenditures of $1,285 million. AMI components such as smart meters, a communication network, information technology systems and business applications, will facilitate REV initiatives. The plan provides for full deployment of AMI to CECONY’s customers by 2022. The NYSPSC also authorized O&R to expend $98.5 million to install AMI for its New York customers, which work was complete as of December 31, 2020.

The NYSPSC began to change compensation for DER and phase out net energy metering (NEM) in 2015. In New York, NEM compensates kilowatt-hours exported to the electric distribution system at the full-service rate for production, delivery, taxes and fees. NYSPSC’s policy is to phase in changes to limit annual bill increases to two percent, reducing the impact of this policy on non-participating residential customers that would have occurred under NEM, but the NYSPSC have permitted exceptions to this policy.

Energy Efficiency, Electric Vehicles and Energy Storage

In January 2020, the NYSPSC issued an order directing energy efficiency targets and budgets for New York utilities. The order approved $2,000 million statewide for electric and gas energy efficiency programs and heat pump budgets, and associated targets, for the years 2021 through 2025 to meet the NYSPSC’s goal of reducing electric use by 3 percent annually and gas use by 1.3 percent annually by 2025. The order authorized budgets for the years 2021 through 2025 for: electric energy efficiency programs of $593 million and $13 million for CECONY and O&R, respectively; gas energy efficiency programs of $235 million and $12 million for CECONY and O&R, respectively; and heat pump programs of $227 million and $15 million for CECONY and O&R, respectively. CECONY’s current electric and gas rate plans allow it to recover the costs of energy efficiency expenditures, including a full rate of return, in rates from customers. Previously, CECONY recovered the costs of its energy efficiency programs from its customers primarily through energy efficiency tracker surcharge mechanisms approved by the NYSPSC. CECONY billed customers approximately $100 million annually between 2016 and 2019, through these mechanisms. Pursuant to CECONY's previous electric rate plan, the company supplemented its energy efficiency transition implementation plan with new energy efficiency, electric vehicle and system peak reduction programs, at a total cost of $177 million from 2017 through 2019, that has been reflected in base rates. See Note B to the financial statements in Item 8.

38 CON EDISON ANNUAL REPORT 2020

In May 2018, the NYSPSC initiated a proceeding on the role of electric utilities in providing needed infrastructure and rate options to advance adoption of electric vehicles. In July 2020, the NYSPSC established a light-duty electric vehicle make-ready program that includes budgets of $290 million and $24 million for CECONY and O&R, respectively, through 2025 for electric vehicle infrastructure and related program costs. CECONY’s current electric rate plan also includes funding to offer up to $22 million in incentives for off-peak charging and electric vehicle infrastructure. The NYSPSC authorized both CECONY and O&R to recover these costs, including a full rate of return, in rates from customers.

In December 2018, the NYSPSC issued an order establishing an energy storage goal of up to 3,000 MW of energy storage by 2030 with an interim objective of 1,500 MW by 2025. The order also required CECONY to file an implementation plan for a competitive procurement process to deploy 300 MW of energy storage while O&R and the other New York electric utilities must plan to deploy 10 MW each. CECONY and O&R filed their implementation plans in February 2019. In December 2020, CECONY entered into a contract with a storage developer for energy storage services to provide power capacity of up to 100 MW. The Utilities expect to recover the cost of energy storage services, including a full rate of return, in rates from customers.

Climate Change

As indicated by the Intergovernmental Panel on Climate Change, emissions of greenhouse gases (GHG), including carbon dioxide, are very likely changing the world’s climate.

Climate change could affect customer demand for the Companies’ energy services. It might also cause physical damage to the Companies’ facilities and disruption of their operations due to more frequent and more extreme weather. In August 2020, Tropical Storm Isaias caused significant damage to the Utilities’ electric distribution systems and interrupted service to approximately 530,000 of the Utilities’ customers and caused the second-largest power outage in the Utilities’ history (Superstorm Sandy interrupted service to 1.4 million of the Utilities’ customers’ in October 2012) and resulted in the Utilities incurring substantial response and restoration costs. After Superstorm Sandy, CECONY invested $1,000 million in its infrastructure in order to improve its resilience against storms. In December 2019, CECONY completed a study of climate change vulnerability. The study evaluated present-day infrastructure, design specifications and procedures under a range of potential climate futures. The study identified sea level rise, coastal storm surge, inland flooding from intense rainfall, hurricane-strength winds and extreme heat to be CECONY’s most significant climate-driven risks to its electric, gas and steam systems. The study estimated that CECONY might need to invest between $1,800 million and $5,200 million by 2050 on targeted programs in order to adapt to potential impacts from climate change. During 2020, CECONY further evaluated its future climate change adaptation strategies and developed a climate change implementation plan that it filed with the NYSPSC in December 2020. The climate change implementation plan explains how CECONY will incorporate climate change projections for heat, precipitation, and sea level rise from the 2019 Climate Change Vulnerability Study into its operations to mitigate climate change risks to its assets and operations and establishes an ongoing process to reflect the latest science in the company’s planning. With respect to governance, CECONY is adopting a climate change planning and design guideline, creating an executive committee to oversee implementation of the plan, and is establishing a climate risk and resilience team to execute the day-to-day activities required by the plan.

Based on the most recent data (2018) published by the U.S. Environmental Protection Agency (EPA), Con Edison estimates that its direct GHG emissions constitute less than 0.1 percent of the nation’s GHG emissions. Transportation is the largest source of GHG emissions in New York State. Con Edison’s estimated emissions of GHG during the past five years were:

(Metric tons, in millions (a))	2016	2017	2018	2019	2020
CO2 equivalent emissions	3.1	3.0	3.1	2.9	2.7

(a)Estimated emissions for 2020 are based on preliminary data and are subject to third-party verification.

Con Edison’s more than 50 percent decrease in direct GHG emissions (carbon dioxide, methane and sulfur hexafluoride) from the 2005 baseline (6.0 million metric tons) reflects the emission reductions resulting from equipment and repair projects, reduced steam demand, the increased use of natural gas in lieu of fuel oil at CECONY’s steam production facilities as well as projects to reduce sulfur hexafluoride emissions and to replace gas distribution pipes.

CECONY has participated for several years in voluntary initiatives with the EPA to reduce its methane and sulfur hexafluoride emissions. The Utilities reduce methane emissions from the operation of their gas distribution systems through pipe maintenance and replacement programs and by introducing new technologies to reduce fugitive emissions from leaks or when work is performed on operating assets. The Utilities reduce emissions of sulfur hexafluoride, which is used for arc suppression in substation circuit breakers and switches, by using improved

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technologies to locate and repair leaks and by replacing older equipment. The Utilities also actively promote energy efficiency and the use of renewable generation to help their customers reduce their GHG emissions.

Emissions are also avoided by renewable electric production facilities replacing fossil-fueled electric production facilities and the continued operation of upstate nuclear power plants. See – “Clean Energy Future,” above. NYSERDA has been responsible for implementing the renewable portfolio standard (RPS) and Clean Energy Standard (CES) established by the NYSPSC. NYSERDA has entered into agreements with developers of large renewable electric production facilities and the owners of upstate nuclear power plants and pays them premiums based on the facilities’ electric output. These facilities sell their energy output in the wholesale energy and capacity markets administered by the NYISO. As a result of the Utilities’ participation in the NYISO wholesale markets, a portion of the Utilities’ NYISO energy purchases are sourced from renewable electric production facilities. NYSERDA also has provided rebates to customers who installed eligible renewable electric production technologies. The electricity produced by such customer-sited renewables generation offsets the energy that the Utilities would otherwise have procured, thereby reducing the amount of electricity produced by non-renewable production facilities.

In 2019, NYSERDA and the New York State Department of Environmental Conservation (NYSDEC) published the New York State Greenhouse Gas Inventory, which reported that emissions from electricity generated in-state decreased 56 percent between 1990 and 2016 due, in part, to the decrease in the burning of coal and petroleum products in the electricity generation sector in New York and the increase in renewables generation in New York.

In January 2016, the NYSPSC approved a 10-year $5,300 million clean energy fund to be managed by NYSERDA under the NYSPSC's supervision. The clean energy fund has four portfolios: market development; innovation and research; NY Green Bank and NY Sun. The Utilities collect all clean energy fund surcharges through the system benefit charge (including previously authorized RPS, EEPS, Technology and Market Development collections and incremental clean energy fund collections to be collected from electric customers only). The Utilities billed customers clean energy fund surcharges of $212 million, $305 million and $311 million in 2020, 2019, and 2018 respectively. For information about NYSPSC proceedings considering renewable generation see “Clean Energy Future," above.

CECONY is subject to carbon dioxide emissions regulations established by New York State under the Regional Greenhouse Gas Initiative (RGGI). The initiative, a cooperative effort by Northeastern and Mid-Atlantic states, established a decreasing cap on carbon dioxide emissions resulting from the generation of electricity. Under RGGI, affected electric generators are required to obtain emission allowances to cover their carbon dioxide emissions, available primarily through auctions administered by participating states or a secondary market. For the fourth RGGI control period (2018-2020), CECONY purchased allowances for 7.4 million short tons to meet its control period obligation, which is expected to be 6.4 million short tons. Due to changes in the New York State CO2 Budget Trading Program, for the fifth RGGI control period (2021 - 2023) CECONY expects two additional company facilities will be added to the RGGI program. However, since the affected units at these facilities are used only for peaking generation and when needed to restore power to the electric grid, these changes are not expected to materially impact the company’s RGGI obligations. CECONY will purchase RGGI allowances for the fifth control period based on anticipated emissions, which are expected to be similar to past compliance periods.

The cost to the Companies to comply with legislation, regulations or initiatives limiting GHG emissions could be substantial.

Environmental Sustainability

Con Edison’s sustainability strategy, as it relates to the environment, provides that the company is dedicated to making a transformational impact on the environment, our region, and the lives of the people we serve. As part of its strategy, the company seeks, among other things, to reduce direct and indirect emissions; enhance the efficiency of its water use; minimize its impact to natural ecosystems; focus on reducing, reusing and recycling to minimize consumption; and design its work in consideration of climate forecasts. Con Edison has adopted a clean energy commitment to further implement its sustainability strategy. The company’s clean energy commitment seeks to triple energy efficiency investments by 2030; achieve 100 percent clean electricity in New York State by 2040; transition the Utilities’ fleet of light-duty vehicles to electric vehicles; provide all-in support for electric vehicles across the Utilities’ service area; and accelerate the reduction of fossil fuels for building heating.

CECONY

Superfund

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 costs, remediation costs and environmental damages. The sites as to which CECONY has been asserted to have liability under Superfund include its and its predecessor companies’ former manufactured gas sites, its multi-purpose Astoria site, the Gowanus Canal site, the Newtown Creek site and other Superfund sites discussed below. There may be additional sites as to which assertions will be made that the company has liability. For a further discussion of claims and possible claims against the company under Superfund, estimated liability accrued for Superfund claims and recovery from customers of site investigation and remediation costs, see Note G to the financial statements in Item 8.

Manufactured Gas Sites

CECONY and its predecessors formerly owned and operated manufactured gas plants at 51 sites (MGP Sites) in New York City and Westchester County. Many of these sites have been subdivided and are now owned by parties other than CECONY and have been redeveloped for other uses, including schools, residential and commercial developments and hospitals. The NYSDEC is requiring CECONY to investigate, and if necessary, develop and implement remediation programs for the sites, including any neighboring areas to which contamination may have migrated.

CECONY has started remedial investigations at all 51 MGP Sites. After investigations, no MGP impacts have been detected at all or portions of 15 sites, and the NYSDEC has issued No Further Action (NFA) letters for these sites.

Coal tar or other MGP-related contaminants have been detected at the remaining 36 sites. Remedial actions have been completed at all or portions of 14 sites and the NYSDEC has issued NFA letters for these sites. In addition, remedial actions have been completed by property owners at all or portions of four sites under the NYS Brownfield Cleanup Program and Certificates of Completion have been issued by the NYSDEC for these sites. Remedial design, planning or action is ongoing for the remaining sites or portions of sites; however, the information as to the extent of contamination and scope of the remediation likely to be required for many of these sites is incomplete. The company estimates that its undiscounted potential liability for the completion of the site investigation and cleanup of the known contamination on MGP sites (other than the Astoria site, which is discussed below) could range from $576 million to $2,194 million.

Astoria Site

CECONY is permitted by the NYSDEC to operate a hazardous waste storage facility on property owned by it in the Astoria section of Queens, New York. Portions of the property were formerly the location of a manufactured gas plant and also have been used or are being used for, among other things, electric generation operations, electric substation operations, the storage of fuel oil and liquefied natural gas and the maintenance and storage of electric equipment. As a condition of its NYSDEC permit, the company is required to investigate the property and, where environmental contamination is found and action is necessary, to remediate the contamination. The company’s investigations are ongoing. The company has submitted reports to the NYSDEC and the New York State Department of Health and in the future will be submitting additional reports identifying the known areas of contamination. The company estimates that its undiscounted potential liability for the completion of the site investigation and cleanup of the known contamination on the property could range from $177 million to $537 million.

Gowanus Canal

In August 2009, CECONY received a notice of potential liability and request for information from the EPA about the operations of the company and its predecessors at sites adjacent to or near the 1.8 mile Gowanus Canal in Brooklyn, New York. In March 2010, the EPA added the Gowanus Canal to its National Priorities List of Superfund sites. The canal’s adjacent waterfront is primarily commercial and industrial, currently consisting of concrete plants, warehouses and parking lots. The canal is near several residential neighborhoods. In September 2013, the EPA issued its record of decision for the site. The EPA concluded that there was significant contamination at the site, including polycyclic aromatic hydrocarbons, polychlorinated biphenyls (PCBs), pesticides, metals and volatile organic compounds. The EPA selected a remedy for the site that includes dredging and disposal of some contaminated sediments and stabilization and capping of contamination that will not be removed. The EPA estimated the cost of the selected remedy to be $506 million (and has indicated the actual cost could be significantly higher). The EPA has identified 39 potentially responsible parties (PRPs) with respect to the site, including CECONY (which the EPA indicated has facilities that may be a source of PCBs at the site). The EPA ordered the PRPs, including CECONY, to coordinate and cooperate with each other to perform and/or fund the remedial design for the selected remedy, which current estimates indicate could cost approximately $103 million. CECONY is funding its allocated share of the remedial design costs along with the other PRPs. In April 2019, the EPA issued an order that requires the PRPs, including CECONY, to: (1) design and perform bulkhead structural support work, including associated access dredging, along certain portions of the upper reaches of the canal, and (2) complete the design work for bulkhead structural support along certain portions of the middle part of the canal. The PRPs and CECONY are coordinating the implementation of this new order. In January 2020, the EPA issued an order that requires six

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PRPs, including CECONY, to initiate the remedial action work in the upper reaches of the canal following the completion of the bulkhead upgrades. The EPA estimated that this work would cost approximately $125 million and require about 30 months to complete. In November 2020, the PRPs began implementation of the work required under this order. Cleanup in other areas of the canal is not addressed by this order. In addition, other Federal agencies and the NYSDEC have previously notified the PRPs of their intent to perform a natural resource damage assessment for the site. CECONY is unable to estimate its exposure to liability for the Gowanus Canal site.

Newtown Creek

In June 2017, CECONY received a notice of potential liability from the EPA with respect to the Newtown Creek site that was listed in 2010 on the EPA’s National Priorities List of Superfund sites. The EPA has identified 18 potentially responsible parties (PRPs) with respect to the site, including CECONY, and has indicated that it will notify the company as additional PRPs are identified and notified by the EPA. Newtown Creek and its tributaries (collectively, Newtown Creek) form a 3.8 mile border between Brooklyn and Queens, New York. Currently, the predominant land use around Newtown Creek includes industrial, petroleum, recycling, manufacturing and distribution facilities and warehouses. Other uses include trucking, concrete manufacture, transportation infrastructure and a wastewater treatment plant. Newtown Creek is near several residential neighborhoods. Six PRPs, not including CECONY, pursuant to an administrative settlement agreement and order on consent the EPA issued to them in 2011, have been performing a remedial investigation of the site. The EPA indicated that sampling events have shown the sediments in Newtown Creek to be contaminated with a wide variety of hazardous substances including PCBs, metals, pesticides, polycyclic aromatic hydrocarbons and volatile organic compounds. The EPA also indicated that it has reason to believe that hazardous substances have come to be released from CECONY facilities into Newtown Creek. The current schedule anticipates completion of a feasibility study for the site during 2022 and issuance of the EPA's record of decision selecting a remedy for the site shortly thereafter. CECONY is unable to estimate its exposure to liability for the Newtown Creek site.

Other Superfund Sites

In 2016, CECONY and another utility responded to a reported dielectric fluid leak at a New Jersey marina on the Hudson River associated with one or two underwater transmission lines, the New Jersey portion of which is owned and operated by the other utility and the New York portion of which is owned and operated by CECONY. In 2017, after the marina owner had cleared substantial debris from its collapsed pier and rip rap material that it had previously placed over and in the vicinity of the underwater transmission lines in an attempt to shore up its failing pier, a dielectric fluid leak was found and repaired on one of the underwater transmission lines. In August 2018, the EPA declared the leak response complete. CECONY, the other utility and the marina owner are involved in litigation in federal court regarding response and repair costs, related damages, and the future of the lines. In August 2020, CECONY and the other utility entered into a settlement with the United States, under which the utilities settled the federal government’s claims for outstanding response costs, without admitting fault and while preserving the utilities’ rights to pursue recovery from the marina owner. CECONY expects that, consistent with the cost allocation provisions of its prior arrangements with the other utility for the transmission lines, the response and repair costs incurred by CECONY, the other utility and government agencies, net of any recovery from the marina owner, will be shared by CECONY and the other utility and that CECONY's share is not reasonably likely to have a material adverse effect on its financial position, results of operations or liquidity.

CECONY is a PRP at additional Superfund sites involving other PRPs and participates in PRP groups at those sites. The company generally is not managing the site investigation and remediation at these multiparty sites. Work at these sites is in various stages, and investigation, remediation and monitoring activities at some of these sites can be expected to continue over extended periods of time. The company believes that it is unlikely that monetary sanctions, such as penalties, will be imposed by any governmental authority with respect to these sites.

The following table lists each of the additional Superfund sites for which the company anticipates it may have liability. The table also shows for each such site its location, the year in which the company was designated or alleged to be a PRP or to otherwise have responsibilities for the site (shown in the table under “Start”), the name of the court or agency in which proceedings for the site are pending and CECONY’s estimated percentage of the total liability for each site. The company currently estimates that its potential liability for investigation, remediation, monitoring and environmental damages in aggregate for the sites below is less than $2 million. Superfund liability is joint and several. The company’s estimate of its liability for each site was determined pursuant to consent decrees, settlement agreements or otherwise and in light of the financial condition of other PRPs. The company’s actual liability could differ substantially from amounts estimated.

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Site	Location	Start	Court or Agency	% of Total Liability
Cortese Landfill	Narrowsburg, NY	1987	EPA	6.0%
Curcio Scrap Metal	Saddle Brook, NJ	1987	EPA	100.0%
Metal Bank of America	Philadelphia, PA	1987	EPA	1.0%
Global Landfill	Old Bridge, NJ	1988	EPA	0.4%
Borne Chemical	Elizabeth, NJ	1997	NJDEP	0.7%
Pure Earth	Vineland, NJ	2018	EPA	to be determined

O&R

Superfund

The sites at which O&R has been asserted to have liability under Superfund include its manufactured gas sites and the Superfund sites discussed below. There may be additional sites as to which assertions will be made that O&R has liability. For a further discussion of claims and possible claims against O&R under Superfund, see Note G to the financial statements in Item 8.

Manufactured Gas Sites

O&R and its predecessors formerly owned and operated manufactured gas plants at seven sites (O&R MGP Sites) in Orange County and Rockland County, New York. Three of these sites are now owned by parties other than O&R, and have been redeveloped by them for residential, commercial or industrial uses. The NYSDEC is requiring O&R to develop and implement remediation programs for the O&R MGP Sites including any neighboring areas to which contamination may have migrated.

O&R has completed remedial investigations at all seven of its MGP sites and has received the NYSDEC’s decision regarding the remedial work to be performed at six of the sites. Of the six sites, O&R has completed remediation at four sites. Remedial construction was conducted on a portion of one of the remaining sites in 2019 and remedial design is ongoing for the other remaining sites. The company estimates that its undiscounted potential liability for the completion of the site investigation and cleanup of the known contamination on MGP sites could range from $77 million to $127 million.

Superfund Sites

O&R is a PRP at Superfund sites involving other PRPs and participates in PRP groups at those sites. The company is not managing the site investigation and remediation at these multiparty Superfund sites. Work at these sites is in various stages, and investigation, remediation and monitoring activities at some of these sites is expected to continue over extended periods of time. The company believes that it is unlikely that monetary sanctions, such as penalties, will be imposed by any governmental authority with respect to these sites.

The following table lists each of the Superfund sites for which the company anticipates it may have liability. The table also shows for each such site its location, the year in which the company was designated or alleged to be a PRP or to otherwise have responsibilities for the site (shown in the table under “Start”), the name of the court or agency in which proceedings for the site are pending and O&R’s estimated percentage of the total liability for each site. The company currently estimates that its potential liability for investigation, remediation, monitoring and environmental damages in aggregate for the sites below is less than $1 million. Superfund liability is joint and several. The company’s estimate of its liability for each site was determined pursuant to consent decrees, settlement agreements or otherwise and in light of the financial condition of other PRPs. The company’s actual liability could differ substantially from amounts estimated.

Site	Location	Start	Court or Agency	% of Total Liability
Metal Bank of America	Philadelphia, PA	1993	EPA	4.6%
Borne Chemical	Elizabeth, NJ	1997	NJDEP	2.3%
Ellis Road	Jacksonville, FL	2011	EPA	0.2%

Other Federal, State and Local Environmental Provisions

Toxic Substances Control Act

Virtually all electric utilities, including CECONY and O&R, own equipment containing PCBs. PCBs are regulated under the Federal Toxic Substances Control Act of 1976. The Utilities have procedures in place to manage and dispose of oil and equipment containing PCBs properly when they are removed from service.

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Water Quality

Under NYSDEC regulations, the operation of CECONY’s generating facilities requires permits for water discharges and water withdrawals. Conditions to the renewal of such permits may include limitations on the operations of the permitted facility or requirements to install certain equipment, the cost of which could be substantial. For information about the company’s generating facilities, see “CECONY – Electric Operations – Electric Facilities” and “Steam Operations – Steam Facilities” above in this Item 1.

Certain governmental authorities are investigating contamination in the Hudson River and the New York Harbor. These waters run through portions of CECONY’s service area. Governmental authorities could require entities that released hazardous substances that contaminated these waters to bear the cost of investigation and remediation, which could be substantial.

Air Quality

Under new source review regulations, an owner of a large generating facility, including CECONY’s steam and steam-electric generating facilities, is required to obtain a permit before making modifications to the facility, other than routine maintenance, repair, or replacement, that increase emissions of pollutants from the facility above specified thresholds. To obtain a permit, the facility owner could be required to install additional pollution controls or otherwise limit emissions from the facility. The company reviews on an on-going basis its planned modifications to its facilities to determine the potential applicability of new source review and similar regulations.

The EPA's Transport Rule (also referred to as the Cross-State Air Pollution Rule), which was implemented in January 2015, established a new cap-and-trade program requiring further reductions in air emissions than the Clean Air Intrastate Rule (CAIR) that it replaced. Under the Transport Rule, utilities are to be allocated emissions allowances and may sell the allowances or buy additional allowances. CECONY requested and received NYSPSC approval to change the provisions under which the company recovers its purchased power costs to provide for costs incurred to purchase emissions allowances and revenues received from the sale of allowances. CECONY complied with the Transport Rule in 2020 and expects to comply with the rule in 2021. In 2020, the EPA proposed changes to the Transport Rule in response to a court decision. The EPA is under a court order to finalize this proposed action by March 15, 2021. If the changes to the Transport Rule are adopted as proposed, the number of allowances allocated to CECONY would decrease and the company would be required to purchase allowances to offset the decreased allocation.

The New York State Department of Environmental Conservation issued regulations in 2019 that 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. See “CECONY – Electric Operations – Electric Supply,” above.

Environmental Matters

For information concerning climate change, environmental sustainability, potential liabilities arising from laws and regulations protecting the environment and other environmental matters, see “Environmental Matters” in Item 1, "Air Quality," above and Note G to the financial statements in Item 8.

State Anti-Takeover Law

New York State law provides that a “domestic corporation,” such as Con Edison, may not consummate a merger, consolidation or similar transaction with the beneficial owner of a 20 percent or greater voting stock interest in the corporation, or with an affiliate of the owner, for five years after the acquisition of the voting stock interest, unless the transaction or the acquisition of the voting stock interest was approved by the corporation’s board of directors prior to the acquisition of the voting stock interest. After the expiration of the five-year period, the transaction may be consummated only pursuant to a stringent “fair price” formula or with the approval of a majority of the disinterested stockholders.

Human Capital

Con Edison is committed to attracting, developing, and retaining a talented, diverse workforce. It values and supports a wide range of employee needs and interests. The company’s skilled and experienced workforce enables the company to maintain best-in-class reliability and progress towards achieving a clean energy future. Human capital measures focus on employee safety, hiring the right talent, employee development and retention, diversity and inclusion, emergency response and providing essential services to customers while protecting employees during the COVID-19 pandemic.

On December 31, 2020, Con Edison and its subsidiaries had 14,071 employees, based entirely in the United States including 12,477 at CECONY; 1,118 at O&R, 468 at the Clean Energy Businesses and 8 at Con Edison

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Transmission. Of the total CECONY and O&R employees, 7,174 and 574 employees, respectively, were represented by a collective bargaining unit. The collective bargaining agreement covering most of the CECONY employees expires in June 2024. Agreements covering other CECONY employees and O&R employees expire in June 2021 and May 2023, respectively.

Con Edison measures the voluntary attrition rate of its employees in assessing the company’s overall human capital. The company has a low annual turnover rate of approximately 6.5 percent, half of which is attributed to retirements. The average length of service is 14 years. Con Edison strives to have a diverse and inclusive workforce. A comprehensive diversity and inclusion strategy underlies the corporate culture; informing how its employees engage with one another, and setting the foundation for a respectful and inclusive environment. On December 31, 2020, women represented 21.9 percent of the total workforce and people of color represented 49 percent of the workforce, with ethnicity breaking down as follows: 51.0 percent White, 20.8 percent Black, 18.1 percent Hispanic, 8.8 percent Asian and 1.3 percent other.

In managing the business, the company focuses heavily on creating a strong safety culture. Continuous focus on safety while performing work is paramount, and leaders and managers are committed to implementing programs and practices that promote the right knowledge, skills, and attitudes to successfully undertake the responsibilities of safety, including required training for both field and office employees. To that end, the company has a dedicated facility, the Learning Center, that offers classes to employees covering technical courses, skills enhancement, safety, and leadership development. During 2020, employees spent almost 500,000 hours in instructor-led training. Further, the company maintains a career development and succession planning program that is committed to helping employees grow their careers, talents, skills and abilities. In addition to their daily job functions, employees of the Utilities are assigned to and trained on a position for emergency response that is mobilized in the event of a weather event or emergency.

As a result of the COVID-19 pandemic, 60 percent of the total workforce was working remotely as of December 31, 2020. The viability of a mobile workforce was made possible by digital software and smart device capabilities that helped employees to collaborate with each other and remain productive while complying with health requirements. Even as the company continues to respond to the pandemic, the entire CECONY and O&R workforce is available in the event of an emergency that requires on-site presence. During 2020, Con Edison and its subsidiaries managed their operations and resources while avoiding lay-offs and furloughs and continued to recruit, interview, and hire internal and external applicants to fill critical positions. Con Edison, and its subsidiaries support employee health through mandatory pre-entry symptom surveys for employees arriving at all company locations, regular cleaning and disinfecting of all work and common areas, promoting social distancing, requiring face coverings, and directing employees to work remotely whenever possible.

Available Information

For the sources of information about the Companies, see “Available Information” in the “Introduction” appearing before this Item 1.

Item 1A: Risk Factors

Information in any item of this report as to which reference is made in this Item 1A is incorporated by reference herein. The use of such terms as “see” or “refer to” shall be deemed to incorporate at the place such term is used the information to which such reference is made.

The Companies’ businesses are influenced by many factors that are difficult to predict, and that involve uncertainties that may materially affect actual operating results, cash flows and financial condition.

The Companies have established an enterprise risk management program to identify, assess, manage and monitor its major business risks based on established criteria for the severity of an event, the likelihood of its occurrence, and the programs in place to control the event or reduce the impact. The Companies’ major risks include:

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Regulatory/Compliance Risks:

The Companies Are Extensively Regulated And Are Subject To Substantial Penalties.    The Companies’ operations require numerous permits, approvals and certificates from various federal, state and local governmental agencies. State utility regulators may seek to impose substantial penalties on the Utilities for violations of state utility laws, regulations or orders. In addition, the Utilities' rate plans usually include negative revenue adjustments for failing to meet certain operating and customer satisfaction standards. In January 2021, Governor Cuomo proposed legislation that, if enacted, would establish an automatic moratorium on disconnections of residential and small business customers by the Utilities during certain states of emergency. In November 2020, the NYSPSC issued orders to show cause why substantial penalties should not be imposed on the Utilities regarding their preparation for and response to Tropical Storm Isaias and on CECONY regarding its actions and/or omissions prior to, during, and after the July 2019 power outages on the west side of Manhattan and in the Flatbush area of Brooklyn. The orders further indicated that should the NYSPSC confirm that certain alleged violations demonstrate a failure by the Utilities to continue to provide safe and adequate service, the NYSPSC would be authorized to commence a proceeding to revoke or modify the Utilities’ operating certificates. See Note B to the financial statements in Item 8. FERC has the authority to impose penalties on the Utilities, the Clean Energy Businesses and the projects that Con Edison Transmission invests in, which could be substantial, for violations of the Federal Power Act, the Natural Gas Act or related rules, including reliability and cyber security rules. Environmental agencies may seek penalties for failure to comply with laws, regulations or permits. The Companies may also be subject to penalties from other regulatory agencies. The Companies may be subject to new laws, regulations or other requirements or the revision or reinterpretation of such requirements, which could adversely affect them. See “Utility Regulation", "Competition" and “Environmental Matters – Climate Change" and "Environmental Matters - Other Federal, State and Local Environmental Provisions” in Item 1, “Application of Critical Accounting Policies” in Item 7 and “COVID-19 Regulatory Matters” and “Other Regulatory Matters” in Note B to the financial statements in Item 8.

The Utilities’ Rate Plans May Not Provide A Reasonable Return.    The Utilities have rate plans approved by state utility regulators that limit the rates they can charge their customers. The rates are generally designed for, but do not guarantee, the recovery of the Utilities’ cost of service (including a return on equity). See “Utility Regulation – State Utility Regulation – Rate Plans” in Item 1 and “Rate Plans” in Note B to the financial statements in Item 8. Rates usually may not be changed during the specified terms of the rate plans other than to recover energy costs and limited other exceptions. The Utilities’ actual costs may exceed levels provided for such costs in the rate plans (see “COVID-19 Regulatory Matters” in Note B to the financial statements in Item 8). State utility regulators can initiate proceedings to prohibit the Utilities from recovering from their customers the cost of service (including energy costs and storm restoration costs) that the regulators determine to have been imprudently incurred (see "Other Regulatory Matters" in Note B to the financial statements in Item 8). The Utilities have from time to time entered into settlement agreements to resolve various prudence proceedings.

The Companies May Be Adversely Affected By Changes To The Utilities’ Rate Plans.    The Utilities’ rate plans typically require action by regulators at their expiration dates, which may include approval of new plans with different provisions. The need to recover from customers increasing costs, taxes or state-mandated assessments or surcharges could adversely affect the Utilities’ opportunity to obtain new rate plans that provide a reasonable rate of return and continue important provisions of current rate plans. The Utilities’ current New York electric and gas rate plans include revenue decoupling mechanisms and their New York electric, gas and steam rate plans include provisions for the recovery of energy costs and reconciliation of the actual amount of pension and other postretirement, environmental and certain other costs to amounts reflected in rates. See “Rate Plans” in Note B to the financial statements in Item 8.

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Operations Risks:

The Failure Of, Or Damage To, The Companies’ Facilities Could Adversely Affect The Companies.    The Utilities provide electricity, gas and steam service using energy facilities, many of which are located either in, or close to, densely populated public places. See the description of the Utilities’ facilities in Item 1. A failure of, or damage to, these facilities, or an error in the operation or maintenance of these facilities, could result in bodily injury or death, property damage, the release of hazardous substances or extended service interruptions. Impacts of climate change, such as sea level rise, coastal storm surge, inland flooding from intense rainfall, hurricane-strength winds and extreme heat could damage facilities and the Utilities may experience more severe consequences from attempting to operate during and after such events. The Utilities’ response to such events may be perceived to be below customer expectations. The Utilities could be required to pay substantial amounts that may not be covered by the Utilities’ insurance policies to repair or replace their facilities, compensate others for injury or death or other damage and settle any proceedings initiated by state utility regulators or other regulatory agencies. The occurrence of such events could also adversely affect the cost and availability of insurance. See “Other Regulatory Matters” in Note B and “Manhattan Explosion and Fire” in Note H to the financial statements in Item 8. Changes to laws, regulations or judicial doctrines could further expand the Utilities’ liability for service interruptions. See “Utility Regulation – State Utility Regulation” and "Environmental Matters – Climate Change" in Item 1.

A Cyber Attack Could Adversely Affect The Companies.    The Companies and other operators of critical energy infrastructure and energy market participants face a heightened risk of cyber attack and the Companies’ businesses require the continued operation of information systems and network infrastructure. See Item 1 for a description of the businesses of the Utilities, the Clean Energy Businesses and Con Edison Transmission. Cyber attacks may include hacking, viruses, malware, denial of service attacks, ransomware or other security breaches, including loss of data. Cyber threats to the electric and gas systems are increasing in sophistication, magnitude and frequency. There has been a growing use of COVID-19 related themes by malicious cyber actors and the significant increase in employees working remotely has increased the attack surface area for the Companies as well as their contractors and vendors.Interconnectivity with customers through advanced metering infrastructure, independent system operators, energy traders and other energy market participants, suppliers, contractors and others also exposes the Companies’ information systems and network infrastructure to an increased risk of cyber incidents, including attacks, and increases the risk that a cyber incident or attack on the Companies could affect others. In the event of a cyber incident or attack that the Companies were unable to defend against or mitigate, the Companies could have their operations and the operations of their customers and others disrupted. The Companies could also have their financial and other information systems and network infrastructure impaired, property damaged, and customer and employee information stolen; experience substantial loss of revenues, response costs and other financial loss; and be subject to increased regulation, litigation, penalties and damage to their reputation. In December 2020, it was announced that updates from SolarWinds, a network monitoring tool used by CECONY, O&R and the Clean Energy Businesses, was compromised and facilitated a cyberattack against multiple private and public sector entities. The Companies have experienced cyber incidents and attacks, including the recent SolarWinds attack, although none of the incidents or attacks had a material impact.

The Failure Of Processes and Systems And The Performance Of Employees And Contractors Could Adversely Affect The Companies.    The Companies have developed business processes and use information and communication systems for operations, customer service, legal compliance, personnel, accounting, planning and other matters. The Companies have completed a multi-year, phased transition of information technology services, including application maintenance and support and infrastructure and operations services, to a contractor. The failure of the Companies’ or its contractors' business processes or information and communication systems or the failure by the Companies’ employees or contractors to follow procedures, their unsafe actions, errors or intentional misconduct, cyber incidents or attacks, or work stoppages could adversely affect the Companies’ operations and liquidity and result in substantial liability, higher costs and increased regulatory requirements. The violation of laws or regulations by employees or contractors for personal gain may result from contract and procurement fraud, extortion, bribe acceptance, fraudulent related-party transactions and serious breaches of corporate policy or standards of business conduct. See “Human Capital” in Item 1.

Environmental Risks:

The Companies Are Exposed To Risks From The Environmental Consequences Of Their Operations.    The Companies are exposed to risks relating to climate change and related matters. In 2019, CECONY completed a climate change vulnerability study and during 2020, CECONY further evaluated its future climate change adaptation strategies and developed a climate change implementation plan. New York State enacted the Climate Leadership and Community Protection Act and New York City enacted the Climate Mobilization Act. See “Environmental Matters – Clean Energy Future” in Item 1. CECONY may also be impacted by regulations requiring reductions in air emissions. See “Environmental Matters – Other Federal, State and Local Environmental Provisions – Air Quality” in Item 1. In addition, the Utilities are responsible for hazardous substances, such as asbestos, PCBs and coal tar, that

                                                                                                                         CON EDISON ANNUAL REPORT 2020 47

have been used or produced in the course of the Utilities’ operations and are present on properties or in facilities and equipment currently or previously owned by them. See “Environmental Matters” in Item 1 and Note G to the financial statements in Item 8. The Companies could be adversely affected if a causal relationship between electric and magnetic fields and adverse health effects were to be established.

Financial and Market Risks:

A Disruption In The Wholesale Energy Markets Or Failure By An Energy Supplier or Customer Could Adversely Affect The Companies.     Almost all the electricity and gas the Utilities sell to their full-service customers is purchased through the wholesale energy markets or pursuant to contracts with energy suppliers. See the description of the Utilities’ energy supply in Item 1. A disruption in the wholesale energy markets or a failure on the part of the Utilities’ energy suppliers or operators of energy delivery systems that connect to the Utilities’ energy facilities could adversely affect their ability to meet their customers’ energy needs and adversely affect the Companies. The Utilities' ability to gain access to additional energy supplies, if needed, depends on effective markets and siting approvals for developer projects, which the Utilities do not control. See “CECONY - Gas Peak Demand” in Item 1. The Clean Energy Businesses sell the output of their renewable electric production projects under long-term power purchase agreements with utilities and municipalities, and a failure of the production projects could adversely affect Con Edison.

The Companies Have Substantial Unfunded Pension And Other Postretirement Benefit Liabilities.    The Utilities have substantial unfunded pension and other postretirement benefit liabilities. The Utilities expect to make substantial contributions to their pension and other postretirement benefit plans. Significant declines in the market values of the investments held to fund pension and other postretirement benefits could trigger substantial funding requirements under governmental regulations. See “Application of Critical Accounting Policies – Accounting for Pensions and Other Postretirement Benefits” and “Financial and Commodity Market Risks” in Item 7 and Notes E and F to the financial statements in Item 8.

Con Edison’s Ability To Pay Dividends Or Interest Depends On Dividends From Its Subsidiaries.    Con Edison’s ability to pay dividends on its common stock or interest on its external borrowings depends primarily on the dividends and other distributions it receives from its subsidiaries. The dividends that the Utilities may pay to Con Edison are limited by the NYSPSC to not more than 100 percent of their respective income available for dividends calculated on a two-year rolling average basis, with certain exceptions. See “Dividends” in Note C and Note T to the financial statements in Item 8.

The Companies Require Access To Capital Markets To Satisfy Funding Requirements.    The Utilities estimate that their construction expenditures will exceed $10,800 million over the next three years. The Utilities use internally-generated funds, equity contributions from Con Edison, if any, and external borrowings to fund the construction expenditures. The Clean Energy Businesses are investing in renewable generation and sustainable energy infrastructure projects that require funds in excess of those produced in the businesses. Con Edison expects to finance its capital requirements primarily through internally generated funds, the sale of its common shares or external borrowings. Changes in financial market conditions or in the Companies’ credit ratings could adversely affect their ability to raise new capital and the cost thereof. See “Capital Requirements and Resources” in Item 1.

Changes To Tax Laws Could Adversely Affect the Companies.  Changes to tax laws, regulations or interpretations thereof could have a material adverse impact on the Companies. Depending on the extent of these changes, the changes could also adversely impact the Companies’ credit ratings and liquidity. The reduction in the federal corporate income tax rate to 21 percent under the TCJA resulted in decreased cash flows from operating activities, and requires increased cash flows from financing activities, for the Utilities. See “Capital Requirements and Resources – Capital Resources” in Item 1, “Liquidity and Capital Resources – Cash Flows from Operating Activities” in Item 7, "Rate Plans" and "Other Regulatory Matters" in Note B and Note L to the financial statements in Item 8.

48 CON EDISON ANNUAL REPORT 2020

Other Risks:

The Companies Face Risks Related To Health Epidemics And Other Outbreaks, Including The COVID-19 Pandemic.    The COVID-19 pandemic has impacted, and continues to impact, countries, communities, supply chains and markets. During 2020, the Companies’ service territories included some of the most severely impacted counties in the United States. As a result of the COVID-19 pandemic, there has been an economic slowdown in the Companies’ service territories, decreased demand for the services that they provide and changes in governmental and regulatory policy. The decline in business activity in the Companies’ service territories has resulted in lower billed sales revenues and increased difficulty of customers to pay bills. Although the Utilities’ New York electric and gas businesses have largely effective revenue decoupling mechanisms in place, lower billed sales revenues and higher uncollectible accounts have impacted and could continue to impact the Companies’ liquidity. The Utilities have also suspended service disconnections, new late payment charges and certain other fees for customers, which may result in a further increase to bad debt expense. The Companies will continue to monitor developments relating to the COVID-19 pandemic; however, the Companies cannot predict the extent to which, COVID-19 may have a material impact on liquidity, financial condition, and results of operations. The situation is changing rapidly and future impacts may materialize that are not yet known. Accordingly, the extent to which COVID-19 may impact these matters will depend on future developments that are highly uncertain and cannot be predicted, including the success of vaccination efforts, actions that federal, state and local governmental or regulatory agencies may continue to take in response to the COVID-19 pandemic, and other actions taken to contain it or treat its impact, among others. See “Coronavirus Disease 2019 (COVID-19) Impacts” in Item 7 and “COVID-19 Regulatory Matters” in Note B.

The Companies’ Strategies May Not Be Effective To Address Changes In The External Business Environment.    The failure to identify, plan and execute strategies to address changes in the external business environment could have a material adverse impact on the Companies. Con Edison seeks to provide shareholder value through continued dividend growth, supported by earnings growth in regulated utilities and contracted electric and gas assets. Changes to public policy, laws or regulations (or interpretations thereof), customer behavior or technology could significantly impact the value of the Utilities’ energy delivery facilities, the Clean Energy Businesses’ renewable and sustainable energy infrastructure projects and Con Edison Transmission's investment in electric and gas transmission projects. Such changes could also affect the Companies’ opportunities to make additional investments in such assets and the potential return on the investments. The Utilities' gas delivery customers and CECONY's steam delivery customers have alternatives, such as electricity and oil. Distributed energy resources, and demand reduction and energy efficiency investments, provide ways for the energy consumers within the Utilities’ service areas to manage their energy usage. The Companies expect distributed energy resources and electric alternatives to gas and steam to increase, and for gas and steam usage to decrease, as the CLCPA and the Climate Mobilization Act continue to be implemented. CECONY established a gas moratorium in March 2019 on new gas service in most of Westchester County. CECONY filed a gas planning analysis with the NYSPSC in July 2020 stating the moratorium could be lifted when increased pipeline capacity is achieved or peak demand is reduced to a level that would enable the company to lift the moratorium and that it is monitoring gas supply constraint in the New York City portion of its service territory. See "Clean Energy Businesses," "Con Edison Transmission," "Environmental Matters - Clean Energy Future" and "Environmental Matters - Climate Change," “Competition” and "CECONY - Gas Peak Demand" in Item 1.

The Companies Also Face Other Risks That Are Beyond Their Control.    The Companies’ results of operations can be affected by circumstances or events that are beyond their control. Weather and energy efficiency efforts directly influence the demand for electricity, gas and steam service, and can affect the price of energy commodities. Terrorist or other physical attacks or acts of war could damage the Companies' facilities. Economic conditions can affect customers’ demand and ability to pay for service, which could adversely affect the Companies.

Item 1B: Unresolved Staff Comments

Con Edison

Con Edison has no unresolved comments from the SEC staff.

CECONY

CECONY has no unresolved comments from the SEC staff.

Item 2:    Properties

Con Edison

Con Edison has no significant properties other than those of the Utilities and the Clean Energy Businesses.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 49

For information about the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, see “Plant and Depreciation” in Note A to the financial statements in Item 8 (which information is incorporated herein by reference).

CECONY

For a discussion of CECONY’s electric, gas and steam facilities, see “CECONY – Electric Operations – Electric Facilities,” “CECONY – Gas Operations – Gas Facilities” and “CECONY – Steam Operations – Steam Facilities” in Item 1 (which information is incorporated herein by reference).

O&R

For a discussion of O&R’s electric and gas facilities, see “O&R – Electric Operations – Electric Facilities” and “O&R – Gas Operations – Gas Facilities” in Item 1 (which information is incorporated herein by reference).

Clean Energy Businesses

For a discussion of the Clean Energy Businesses’ facilities, see “Clean Energy Businesses” in Item 1 (which information is incorporated herein by reference).

Con Edison Transmission

Con Edison Transmission has no properties. Con Edison Transmission has ownership interests in electric and gas transmission companies. For information about these companies, see "Con Edison Transmission" in Item 1 (which information is incorporated herein by reference).

Item 3:    Legal Proceedings

For information about certain legal proceedings affecting the Companies, see “Other Regulatory Matters” in Note B, and “Superfund Sites” and “Asbestos Proceedings” in Note G and “Manhattan Explosion and Fire” in Note H to the financial statements in Item 8 and “Environmental Matters – CECONY – Superfund” and “Environmental Matters – O&R – Superfund” in Item 1 of this report, which information is incorporated herein by reference.

Item 4:    Mine Safety Disclosures

Not applicable.

50 CON EDISON ANNUAL REPORT 2020

Information about our Executive Officers

The following table sets forth certain information about the executive officers of Con Edison as of February 18, 2021. The term of office of each officer, is until the next election of directors (trustees) of their company and until his or her successor is chosen and qualifies. Officers are subject to removal at any time by the board of directors (trustees) of their company.

Name	Age	Offices and Positions During Past Five Years
Timothy P. Cawley	56	12/20 to present – President and Chief Executive Officer and Director of Con Edison and Chief Executive Officer and Trustee of CECONY
		1/18 to 12/20 – President of CECONY
		12/13 to 12/17 – President and Chief Executive Officer of O&R
Robert Hoglund	59	9/05 to present – Senior Vice President and Chief Financial Officer of Con Edison and CECONY
Matthew Ketschke	49	1/21 to present – President of CECONY
		11/17 to 12/20 – Senior Vice President – Customer Energy Solutions
		7/15 to 10/17 – Vice President – Distributed Resource Integration
Robert Sanchez	55	12/17 to present – President and Chief Executive Officer of O&R
		11/17 – Senior Vice President of CECONY
		9/16 to 10/17 – Senior Vice President – Corporate Shared Services of CECONY
		9/14 to 8/16 – Vice President – Brooklyn & Queens Electric Operations of CECONY
Mark Noyes	56	12/16 to present – President and Chief Executive Officer of Con Edison Clean Energy Businesses, Inc.
		5/16 to present – President and Chief Executive Officer of Consolidated Edison Solutions, Inc.
		10/15 to present – President and Chief Executive Officer of Consolidated Edison Development, Inc. and Consolidated Edison Energy, Inc.
Stuart Nachmias	56	1/20 to present – President and Chief Executive Officer of Con Edison Transmission, Inc.
		05/08 to 12/19 – Vice President of Energy Policy and Regulatory Affairs of CECONY
Deneen L. Donnley	56	1/20 to present – Senior Vice President and General Counsel of Con Edison and CECONY
		10/19 to 12/19 – Senior Vice President of Con Edison and CECONY
		9/15 to 10/19 – Executive Vice President, Chief Legal Officer and Corporate Secretary – USAA
Frances A. Resheske	60	2/02 to present – Senior Vice President – Corporate Affairs of CECONY
Mary E. Kelly	52	11/17 to present – Senior Vice President – Corporate Shared Services of CECONY
		1/16 to 10/17 – Vice President – Gas Engineering
		1/14 to 12/15 – Vice President – Construction
Lore de la Bastide	59	7/19 to present – Senior Vice President – Utility Shared Services of CECONY
		6/19 – Senior Vice President of CECONY
		11/14 to 5/19 – Vice President and General Auditor of CECONY
Joseph Miller	58	1/21 to present – Vice President and Controller of Con Edison and CECONY
		1/21 to present – Chief Financial Officer and Controller of O&R
		8/06 to 12/20 – Assistant Controller of Corporate Accounting of CECONY
Yukari Saegusa	53	9/16 to present – Treasurer of Con Edison and CECONY
		8/16 to present – Vice President of Con Edison and CECONY
		8/13 to present – Treasurer of O&R
		3/13 to 7/16 – Director of Corporate Finance of CECONY
Gurudatta Nadkarni	55	1/08 to present – Vice President of Strategic Planning of CECONY

                                                                                                                         CON EDISON ANNUAL REPORT 2020 51

Part II

Item 5:    Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Con Edison

Con Edison’s Common Shares ($.10 par value), the only class of common equity of Con Edison, are traded on the New York Stock Exchange under the trading symbol "ED." As of January 31, 2021, there were 40,198 holders of record of Con Edison’s Common Shares. Con Edison paid quarterly dividends of 74 cents per Common Share in 2019 and quarterly dividends of 76.5 cents per Common Share in 2020. On January 21, 2021, Con Edison declared a quarterly dividend of 77.5 cents per Common Share that is payable on March 15, 2021. Con Edison expects to pay dividends to its shareholders primarily from dividends and other distributions it receives from its subsidiaries. The payment of future dividends is subject to approval and declaration by Con Edison’s Board of Directors and will depend on a variety of factors including business, financial and regulatory considerations. For additional information about the payment of dividends by the Utilities to Con Edison, and restrictions thereon, see “Dividends” in Note C to the financial statements in Item 8 (which information is incorporated herein by reference).

During 2020, the market price of Con Edison’s Common Shares decreased by 20.1 percent (from $90.47 at year-end 2019 to $72.27 at year-end 2020). By comparison, the S&P 500 Index increased 16.3 percent and the S&P 500 Utilities Index decreased 2.8 percent. The total return to Con Edison’s common shareholders during 2020, including both price depreciation and investment of dividends, was (17) percent. By comparison, the total returns for the S&P 500 Index and the S&P 500 Utilities Index were 18.4 percent and 0.5 percent, respectively. For the five-year period 2016 through 2020 inclusive, Con Edison’s shareholders’ total return was 34.7 percent, compared with total returns for the S&P 500 Index and the S&P 500 Utilities Index of 103.0 percent and 72.3 percent, respectively.

	Years Ended December 31,
Company / Index	2015	2016	2017	2018	2019	2020
Consolidated Edison, Inc.	100.00	118.90	141.84	132.45	162.31	134.73
S&P 500 Index	100.00	111.96	136.40	130.42	171.49	203.04
S&P Utilities	100.00	116.29	130.36	135.72	171.48	172.31

Based on $100 invested at December 31, 2015, reinvestment of all dividends in equivalent shares of stock and market price changes on all such shares.

52 CON EDISON ANNUAL REPORT 2020

CECONY

The outstanding shares of CECONY’s Common Stock ($2.50 par value) are the only class of common equity of CECONY. They are held by Con Edison and are not traded.

The dividends declared by CECONY in 2019 and 2020 are shown in its Consolidated Statement of Shareholder’s Equity included in Item 8 (which information is incorporated herein by reference). For additional information about the payment of dividends by CECONY, and restrictions thereon, see “Dividends” in Note C to the financial statements in Item 8 (which information is incorporated herein by reference).

Item 6:    Selected Financial Data

For selected financial data of Con Edison and CECONY, see “Introduction” appearing before Item 1 (which selected financial data is incorporated herein by reference).

                                                                                                                         CON EDISON ANNUAL REPORT 2020 53

Item 7:    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 relates to the consolidated financial statements included in this report of two separate registrants: Con Edison and CECONY, and should be read in conjunction with the financial statements and the notes thereto. As used in this report, the term the “Companies” refers to Con Edison and CECONY. CECONY is a subsidiary of Con Edison and, as such, information in this management’s discussion and analysis about CECONY applies to Con Edison.

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.

Corporate Overview

Con Edison’s principal business operations are those of the Utilities. Con Edison's business operations also include those of the Clean Energy Businesses and Con Edison Transmission. See “Significant Developments and Outlook” in the Introduction to this report, “The Utilities,” “Clean Energy Businesses” and "Con Edison Transmission" in Item 1, and segment financial information in Note O to the financial statements in Item 8. Certain financial data of Con Edison’s businesses are presented below:

	For the Year Ended December 31, 2020						At December 31, 2020
(Millions of Dollars, except percentages)	Operating Revenues			Net Income for Common Stock			Assets
CECONY	$10,647	87	%	$1,185	108	%	$50,967	81	%
O&R	862	7	%	71	6	%	3,247	5	%
Total Utilities	11,509	94	%	1,256	114	%	54,214	86	%
Clean Energy Businesses (a)	736	6	%	24	2	%	6,848	11	%
Con Edison Transmission (b)	4	—	%	(175)	(16)	%	1,348	2	%
Other (c)	(3)	—	%	(4)	—	%	485	1	%
Total Con Edison	$12,246	100	%	$1,101	100	%	$62,895	100	%

(a)Net income for common stock from the Clean Energy Businesses for the year ended December 31, 2020 includes $(43) million of net after-tax mark-to-market losses and reflects $32 million (after-tax) 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 R to the financial statements in Item 8.

(b)Net income for common stock from Con Edison Transmission for the year ended December 31, 2020 includes $(232) million of a net after-tax impairment loss related to its investment in Mountain Valley Pipeline, LLC. See "Application of Critical Accounting Policies - Investments" in Item 7 and "Investments" in Note A to the financial statements in Item 8.

(c)Other includes parent company and consolidation adjustments. Net income for common stock includes $9 million of income tax impact for the impairment loss related to investment in Mountain Valley Pipeline, LLC.

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 mandatory pre-entry symptom surveys for employees arriving at all company locations, regular cleaning and disinfecting of all work and common areas, promoting social distancing and directing employees to work remotely whenever possible. 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. As a result of COVID-19 clusters that have arisen in various areas of New York within the Utilities’ service territory, the Utilities have limited their work in customer premises in the impacted areas to only address emergency, safety-related and selected service connections requested by customers. The Companies have procured an inventory of pandemic-related materials to address anticipated future needs and maintain regular communications with key suppliers.

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 financial statements in Item 8, which information is incorporated herein by reference.

54 CON EDISON ANNUAL REPORT 2020

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 L. 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.

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.

Accounting Considerations

Due to the COVID-19 pandemic and subsequent New York State on PAUSE and related executive orders, decline in business, bankruptcies, layoffs and furloughs, among other factors, both commercial and residential customers may have increased difficulty paying their utility bills. 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 2020, 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 $65 million and $4.6 million at December 31, 2019 to $138 million and $8.7 million at December 31, 2020, respectively. See Note A and "COVID-19 Regulatory Matters" in Note B to the Financial Statements in Item 8.

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 December 31, 2020. See Notes A and K to the financial statements in Item 8.

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 financial statements

                                                                                                                         CON EDISON ANNUAL REPORT 2020 55

in Item 8. However, a continued economic downturn as a result of the COVID-19 pandemic could increase the amount of capital needed by the Utilities and the costs of such capital.

The decline in business activity in the Utilities’ service territory as a result of the COVID-19 pandemic resulted in lower billed sales revenues in 2020 and a slower recovery in cash of outstanding customer accounts receivable balances and is expected to continue to do so in 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 is 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 or later. For the year ended December 31, 2020, the estimated foregone revenues that were not collected by the Utilities were approximately $61 million for CECONY and $3 million for O&R. These foregone revenues have reduced and may continue to reduce liquidity at the Utilities. See Note A and "COVID-19 Regulatory Matters" in Note B to the financial statements in Item 8.

Con Edison and the Utilities also 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 financial statements in Item 8.

Results of Operations

Net income for common stock and earnings per share for the years ended December 31, 2020, 2019 and 2018 were as follows:

(Millions of Dollars, except per share amounts)	Net Income for Common Stock			Earnings per Share
	2020	2019	2018	2020	2019	2018
CECONY	$1,185	$1,250	$1,196	$3.54	$3.80	$3.84
O&R	71	70	59	0.21	0.21	0.19
Clean Energy Businesses (a)(b)	24	(18)	145	0.07	(0.06)	0.46
Con Edison Transmission (c)	(175)	52	47	(0.52)	0.16	0.15
Other (d)	(4)	(11)	(65)	(0.01)	(0.02)	(0.21)
Con Edison (e)	$1,101	$1,343	$1,382	$3.29	$4.09	$4.43

(a)Net income for common stock from the Clean Energy Businesses for the year ended December 31, 2020 and 2019 reflects $32 million or $0.10 a share (after-tax) and $74 million or $0.22 a share (after-tax) 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 R to the financial statements in Item 8. Net income for common stock from the Clean Energy Businesses also includes $(43) million or $(0.13) a share, $(21) million or $(0.07) a share and $(6) million or $(0.02) a share of net after-tax mark-to-market losses in 2020, 2019 and 2018, respectively.

(b)In December 2018, the Clean Energy Businesses acquired Sempra Solar Holdings, LLC. Upon completion of the acquisition, the Clean Energy Businesses recognized an after-tax gain of $89 million or $0.28 per share with respect to jointly-owned renewable energy production projects. See Note V to the financial statements in Item 8.

(c)Net income for common stock from Con Edison Transmission for the year ended December 31, 2020 includes $(232) million or $(0.69) a share of net after-tax impairment loss related to its investment in Mountain Valley Pipeline, LLC. See "Application of Critical Accounting Policies - Investments" in Item 7 and “Investments” in Note A to the financial statements in Item 8.

(d)Other includes parent company and consolidation adjustments. Net income for common stock includes $9 million or $0.03 a share of income tax impact for the impairment loss related to Con Edison Transmission’s investment in Mountain Valley Pipeline, LLC. See “Investments” in Note A to the financial statements in Item 8. Net income for common stock includes $(42) million or $(0.14) a share of income tax expense resulting from a re-measurement of the company's deferred tax assets and liabilities following the issuance of proposed regulations relating to the TCJA for the year ended December 31, 2018. See Note L to the financial statements in Item 8. Net income for common stock for the year ended December 31, 2018 also includes $(8) million or $(0.02) a share of the after-tax transaction costs related to the Clean Energy Businesses' purchase of Sempra Solar Holdings, LLC. See Note V to the financial statements in Item 8.

(e)Earnings per share on a diluted basis were $3.28 a share, $4.08 a share and $4.42 a share in 2020, 2019 and 2018, respectively. See "Earnings Per Common Share" in Note A to the financial statements in Item 8.

56 CON EDISON ANNUAL REPORT 2020

The following tables present the estimated effect of major factors on earnings per share and net income for common stock for the years ended December 31, 2020 as compared with 2019, and 2019 as compared with 2018.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 57

	Variation for the Year Ended December 31, 2020 vs. 2019
	Earnings per Share	Net Income for Common Stock (Millions of Dollars)
CECONY (a)
Changes in rate plans	$0.12	$41	Primarily reflects higher gas net base revenues due to the base rate increase in January 2020 under the company's gas rate plan of $0.20 a share, offset in part by lower steam net revenues of $(0.04) a share due to the impact of the Coronavirus Disease 2019 (COVID-19) pandemic.
Weather impact on steam revenues	(0.10)	(32)	Reflects the impact of warmer winter weather in the 2020 period.
Operations and maintenance expenses	0.82	270	Reflects lower costs for pension and other postretirement benefits of $0.53 a share, which are reconciled under the rate plans, lower regulatory assessments and fees that are collected in revenues from customers of $0.30 a share and lower stock-based compensation of $0.06 a share, offset in part by incremental costs associated with the COVID-19 pandemic of $(0.03) a share and food and medicine spoilage claims related to electric outages caused by Tropical Storm Isaias of $(0.02) a share.
Depreciation, property taxes and other tax matters	(0.88)	(284)	Reflects higher depreciation and amortization expense of $(0.51) a share and higher property taxes of $(0.37) a share, both of which are recoverable under the rate plans, and the absence in 2020 of a reduction in the sales and use tax reserve upon conclusion of the audit assessment of $(0.02) a share, offset in part by, the employee retention tax credit under the CARES Act of $0.02 a share.
Other	(0.22)	(60)	Primarily reflects foregone revenues from the suspension of customers' late payment charges and certain other fees associated with the COVID-19 pandemic of $(0.14) a share and the dilutive effect of Con Edison's stock issuances of $(0.07) a share.
Total CECONY	(0.26)	(65)
O&R (a)
Changes in rate plans	0.05	14	Reflects electric and gas base rate increases of $0.04 a share and $0.01 a share, respectively, under the company's rate plans.
Operations and maintenance expenses	—	(1)	Primarily reflects food and medicine spoilage claims related to electric outages caused by Tropical Storm Isaias.
Depreciation, property taxes and other tax matters	(0.03)	(8)	Reflects higher depreciation and amortization expense and higher property taxes, offset in part, by the employee retention tax credit under the CARES Act.
Other	(0.02)	(4)	Primarily reflects higher costs associated with components of pension and other postretirement benefits other than service cost.
Total O&R	—	1
Clean Energy Businesses
Operating revenues less energy costs	0.06	16	Reflects higher revenues from renewable electric production projects of $0.08 a share, offset in part by lower energy services revenues due to timing of executed contracts of $(0.04) a share.
Operations and maintenance expenses	(0.01)	(3)	Primarily reflects an increase in general operating expenses.
Depreciation and amortization	(0.01)	(3)	Reflects an increase in renewable electric production projects in operation during 2020.
Net interest expense	(0.02)	(8)	Primarily reflects higher unrealized losses on interest rate swaps in the 2020 period.
HLBV effects	0.12	42	Primarily reflects lower losses from tax equity projects in the 2020 period.
Other	(0.01)	(2)	Primarily reflects the absence of a prior period adjustment related to research and development credits recorded in 2019.
Total Clean Energy Businesses	0.13	42
Con Edison Transmission	(0.68)	(227)	Primarily reflects impairment loss related to the investment in Mountain Valley Pipeline, LLC.
Other, including parent company expenses	0.01	7	Primarily reflects lower income tax expense due to impairment loss related to the investment in Mountain Valley Pipeline, LLC.
Total Reported (GAAP basis)	$(0.80)	$(242)
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.

58 CON EDISON ANNUAL REPORT 2020

	Variation for the Years Ended December 31, 2019 vs. 2018
	Earnings per Share	Net Income for Common Stock (Millions of Dollars)
CECONY (a)
Changes in rate plans	$0.76	$240	Reflects higher electric and gas net base revenues of $0.53 a share and $0.16 a share, respectively, primarily due to electric and gas base rate increases in January 2019 under the company's rate plans, higher incentives earned under the electric earnings adjustment mechanisms and positive incentives of $0.06 a share, and growth in the number of gas customers of $0.03 a share, offset in part by electric negative revenue adjustments of $(0.03) a share.
Weather impact on steam revenues	(0.06)	(19)	Reflects the impact of warmer winter weather in 2019.
Operations and maintenance expenses	(0.19)	(58)	Reflects higher costs for pension and other postretirement benefits of $(0.15) a share, which are recoverable under the rate plans, and higher stock-based compensation of $(0.07) a share, offset in part by lower consultant costs of $0.04 a share.
Depreciation, property taxes and other tax matters	(0.54)	(168)	Reflects higher property taxes of $(0.26) a share and higher depreciation and amortization expense of $(0.23) a share, both of which are recoverable under the rate plans, and the absence of New York State sales and use tax refunds received in 2018 of $(0.07) a share, offset in part by lower sales and use tax of $0.02 a share, upon conclusion of the audit assessment.
Other	(0.01)	59	Reflects the dilutive effect of Con Edison's stock issuances of $(0.21) a share, offset in part by lower costs associated with components of pension and other postretirement benefits other than service cost of $0.19 a share.
Total CECONY	(0.04)	54
O&R (a)
Changes in rate plans	0.08	24	Reflects an electric base rate increase, offset in part by a gas base rate decrease under the company's rate plans, effective January 1, 2019.
Operations and maintenance expenses	(0.01)	(3)	Reflects higher stock-based compensation.
Depreciation, property taxes and other tax matters	(0.02)	(6)	Reflects higher depreciation and amortization expense.
Other	(0.03)	(4)	Includes the dilutive effect of Con Edison's stock issuances of $(0.01) a share.
Total O&R	0.02	11
Clean Energy Businesses
Operating revenues less energy costs	0.53	167	Reflects higher revenues from renewable electric production projects resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC, including the consolidation of certain jointly-owned projects that were previously accounted for as equity investments of $0.81 a share, offset in part by lower engineering, procurement and construction services revenues of $(0.34) a share.
Operations and maintenance expenses	0.15	47	Reflects lower engineering, procurement and construction costs of $0.19 a share and lower energy services costs of $0.04 a share, offset in part by higher costs associated with additional renewable electric production projects in operation resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC. of $(0.06) a share.
Depreciation and amortization	(0.34)	(105)	Reflects an increase in renewable electric production projects resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC.
Net interest expense	(0.29)	(90)	Reflects an increase in debt resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC.
HLBV effects	(0.22)	(74)
Gain on acquisition of Sempra Solar Holdings, LLC, net of transaction costs in 2018	(0.28)	(89)
Other	(0.07)	(19)	Reflects the absence in 2019 of equity income from certain jointly-owned projects that were accounted for as equity investments in 2018 but consolidated after the December 2018 acquisition of Sempra Solar Holdings, LLC.
Total Clean Energy Businesses	(0.52)	(163)
Con Edison Transmission	0.01	5	Reflects higher allowance for funds used during construction from the Mountain Valley Pipeline project.
Other, including parent company expenses	0.19	54	Reflects lower New York State capital tax of $0.02 a share. Also reflects 2018 TCJA re-measurement of $0.14 a share and transaction costs related to the acquisition of Sempra Solar Holdings, LLC of $0.02 a share.
Total Reported (GAAP basis)	$(0.34)	$(39)
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.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 59

The Companies’ other operations and maintenance expenses for the years ended December 31, 2020, 2019 and 2018 were as follows:

(Millions of Dollars)	2020	2019	2018
CECONY
Operations	$1,606	$1,563	$1,553
Pensions and other postretirement benefits	(103)	134	71
Health care and other benefits	151	170	166
Regulatory fees and assessments (a)	330	464	444
Other	285	304	321
Total CECONY	2,269	2,635	2,555
O&R	310	308	305
Clean Energy Businesses	228	223	287
Con Edison Transmission	11	9	10
Other (b)	(4)	—	(5)
Total other operations and maintenance expenses	$2,814	$3,175	$3,152

(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.

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. A discussion of the results of operations by principal business segment for the years ended December 31, 2020, 2019 and 2018 follows. For additional business segment financial information, see Note O to the financial statements in Item 8.

60 CON EDISON ANNUAL REPORT 2020

The Companies’ results of operations for the years ended December 31, 2020, 2019 and 2018 were:

	CECONY			O&R			Clean Energy Businesses			Con Edison Transmission			Other (a)			Con Edison (b)
(Millions of Dollars)	2020	2019	2018	2020	2019	2018	2020	2019	2018	2020	2019	2018	2020	2019	2018	2020	2019	2018
Operating revenues	$10,647	$10,821	$10,680	$862	$893	$891	$736	$857	$763	$4	$4	$4	$(3)	$(1)	$(1)	$12,246	$12,574	$12,337
Purchased power	1,432	1,357	1,433	169	188	208	—	—	2	—	—	—	(1)	1	1	1,600	1,546	1,644
Fuel	156	207	263	—	—	—	—	—	—	—	—	—	—	—	—	156	207	263
Gas purchased for resale	426	606	643	61	90	86	41	185	313	—	—	—	(1)	(1)	(1)	527	880	1,041
Other operations and maintenance	2,269	2,635	2,555	310	308	305	228	223	287	11	9	10	(4)	—	(5)	2,814	3,175	3,152
Depreciation and amortization	1,598	1,373	1,276	90	84	77	231	226	85	1	1	1	—	—	(1)	1,920	1,684	1,438
Taxes, other than income taxes	2,456	2,295	2,156	85	84	83	21	21	13	—	—	—	13	6	14	2,575	2,406	2,266
Gain on acquisition of Sempra Solar Holdings, LLC (c)	—	—	—	—	—	—	—	—	131	—	—	—	—	—	—	—	—	131
Operating income	2,310	2,348	2,354	147	139	132	215	202	194	(8)	(6)	(7)	(10)	(7)	(9)	2,654	2,676	2,664
Other income less deductions (d)	(171)	(35)	(143)	(14)	(11)	(19)	4	5	33	(215)	104	91	(5)	(12)	(24)	(401)	51	(62)
Net interest expense	739	728	689	41	41	39	196	186	63	18	25	20	25	11	8	1,019	991	819
Income before income tax expense	1,400	1,585	1,522	92	87	74	23	21	164	(241)	73	64	(40)	(30)	(41)	1,234	1,736	1,783
Income tax expense	215	335	326	21	17	15	(44)	(58)	19	(66)	21	17	(36)	(19)	24	90	296	401
Net income	$1,185	$1,250	$1,196	$71	$70	$59	$67	$79	$145	$(175)	$52	$47	$(4)	$(11)	$(65)	$1,144	$1,440	$1,382
Income attributable to non-controlling interest	—	—	—	—	—	—	43	97	—	—	—	—	—	—	—	43	97	—
Net income from common stock	$1,185	$1,250	$1,196	$71	$70	$59	$24	$(18)	$145	$(175)	$52	$47	$(4)	$(11)	$(65)	$1,101	$1,343	$1,382

(a) Includes parent company and consolidation adjustments.

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

(c) See Note V to the financial statements in Item 8.

(d) For the year ended December 31, 2020, Con Edison Transmission recorded a pre-tax impairment loss of $320 million ($223 million, after tax), to reduce the carrying value of its investment in MVP from $662 million to $342 million. See “Investments” in Note A to the financial statements in Item 8.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 61

Year Ended December 31, 2020 Compared with Year Ended December 31, 2019

CECONY

	For the Year Ended December 31, 2020				For the Year Ended December 31, 2019
(Millions of Dollars)	Electric	Gas	Steam	2020 Total	Electric	Gas	Steam	2019 Total	2020-2019 Variation
Operating revenues	$8,103	$2,036	$508	$10,647	$8,062	$2,132	$627	$10,821	$(174)
Purchased power	1,405	—	27	1,432	1,324	—	33	1,357	75
Fuel	75	—	81	156	99	—	108	207	(51)
Gas purchased for resale	—	426	—	426	—	606	—	606	(180)
Other operations and maintenance	1,753	355	161	2,269	2,059	399	177	2,635	(366)
Depreciation and amortization	1,214	294	90	1,598	1,053	231	89	1,373	225
Taxes, other than income taxes	1,925	387	144	2,456	1,769	368	158	2,295	161
Operating income	$1,731	$574	$5	$2,310	$1,758	$528	$62	$2,348	$(38)

Electric

CECONY’s results of electric operations for the year ended December 31, 2020 compared with the year ended December 31, 2019 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	Variation
Operating revenues	$8,103	$8,062	$41
Purchased power	1,405	1,324	81
Fuel	75	99	(24)
Other operations and maintenance	1,753	2,059	(306)
Depreciation and amortization	1,214	1,053	161
Taxes, other than income taxes	1,925	1,769	156
Electric operating income	$1,731	$1,758	$(27)

CECONY’s electric sales and deliveries in 2020 compared with 2019 were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Years Ended						For the Years Ended
Description	December 31, 2020	December 31, 2019	Variation	Percent Variation			December 31, 2020	December 31, 2019	Variation	Percent Variation
Residential/Religious (b)	11,107	10,560	547	5.2	%		$2,901	$2,671	$230	8.6	%
Commercial/Industrial	9,280	9,908	(628)	(6.3)			1,876	1,845	31	1.7
Retail choice customers	22,000	24,754	(2,754)	(11.1)			2,391	2,470	(79)	(3.2)
NYPA, Municipal Agency and other sales	9,184	9,932	(748)	(7.5)			665	663	2	0.3
Other operating revenues (c)	—	—	—	—			270	413	(143)	(34.6)
Total	51,571	55,154	(3,583)	(6.5)	%	(d)	$8,103	$8,062	$41	0.5	%

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

(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 plan.

(d)After adjusting for variations, primarily weather and billing days, electric delivery volumes in the company’s service area decreased 6.1 percent in 2020 compared with 2019. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues increased $41 million in 2020 compared with 2019 primarily due to higher purchased power expenses ($81 million), offset in part by lower fuel expenses ($24 million) and lower revenues from the electric rate plan ($16 million).

Purchased power expenses increased $81 million in 2020 compared with 2019 due to higher unit costs ($158 million), offset in part by lower purchased volumes ($77 million).

62 CON EDISON ANNUAL REPORT 2020

Fuel expenses decreased $24 million in 2020 compared with 2019 due to lower unit costs ($31 million), offset in part by higher purchased volumes from the company’s electric generating facilities ($7 million).

Other operations and maintenance expenses decreased $306 million in 2020 compared with 2019 primarily due to lower costs for pension and other postretirement benefits ($195 million), lower surcharges for assessments and fees that are collected in revenues from customers ($110 million), lower stock-based compensation ($25 million) and lower healthcare costs ($16 million), offset in part by incremental costs associated with the COVID-19 pandemic ($14 million), higher municipal infrastructure support costs ($9 million) and food and medicine spoilage claims related to outages caused by Tropical Storm Isaias ($7 million).

Depreciation and amortization increased $161 million in 2020 compared with 2019 primarily due to higher electric utility plant balances and higher depreciation rates.

Taxes, other than income taxes increased $156 million in 2020 compared with 2019 primarily due to higher property taxes ($105 million), lower deferral of under-collected property taxes ($38 million), higher state and local taxes ($11 million) and the absence in 2020 of a reduction in the sales and use tax reserve upon conclusion of the audit assessment ($5 million), offset in part by lower payroll taxes ($3 million) due to the Employee Retention Tax Credit created under the CARES Act. See “Coronavirus Disease 2019 (COVID-19) Impacts - Impact of CARES Act and 2021 Appropriations Act on Accounting for Income Taxes,” above.

Gas

CECONY’s results of gas operations for the year ended December 31, 2020 compared with the year ended December 31, 2019 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	Variation
Operating revenues	$2,036	$2,132	$(96)
Gas purchased for resale	426	606	(180)
Other operations and maintenance	355	399	(44)
Depreciation and amortization	294	231	63
Taxes, other than income taxes	387	368	19
Gas operating income	$574	$528	$46

CECONY’s gas sales and deliveries, excluding off-system sales, in 2020 compared with 2019 were:

	Thousands of Dt Delivered						Revenues in Millions (a)
	For the Years Ended						For the Years Ended
Description	December 31, 2020	December 31, 2019	Variation	Percent Variation			December 31, 2020	December 31, 2019	Variation	Percent Variation
Residential	48,999	54,402	(5,403)	(9.9)	%		$911	$943	$(32)	(3.4)	%
General	29,516	33,235	(3,719)	(11.2)			318	384	(66)	(17.2)
Firm transportation	76,614	81,710	(5,096)	(6.2)			649	593	56	9.4
Total firm sales and transportation	155,129	169,347	(14,218)	(8.4)		(b)	1,878	1,920	(42)	(2.2)
Interruptible sales (c)	8,482	9,903	(1,421)	(14.3)			27	42	(15)	(35.7)
NYPA	41,577	39,643	1,934	4.9			2	2	—	—
Generation plants	49,723	52,011	(2,288)	(4.4)			22	23	(1)	(4.3)
Other	20,814	20,701	113	0.5			33	31	2	6.5
Other operating revenues (d)	—	—	—	—			74	114	(40)	(35.1)
Total	275,725	291,605	(15,880)	(5.4)	%		$2,036	$2,132	$(96)	(4.5)	%

(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 0.7 percent in 2020 compared with 2019. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

(c)Includes 3,510 thousands and 5,484 thousands of Dt for 2020 and 2019, 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. See Note B to the financial statements in Item 8.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 63

Operating revenues decreased $96 million in 2020 compared with 2019 primarily due to lower gas purchased for resale expense ($180 million) and certain rate plan reconciliations ($6 million), offset in part by higher gas revenues due to the gas base rates increase in January 2020 under the company's gas rate plan ($91 million).

Gas purchased for resale decreased $180 million in 2020 compared with 2019 due to lower unit costs ($110 million) and lower purchased volumes ($70 million).

Other operations and maintenance expenses decreased $44 million in 2020 compared with 2019 primarily due to lower costs for pension and other postretirement benefits ($31 million), lower stock-based compensation ($5 million), lower municipal infrastructure support costs ($5 million) and lower reserve for injuries and damages ($4 million).

Depreciation and amortization increased $63 million in 2020 compared with 2019 primarily due to higher gas utility plant balances and higher depreciation rates.

Taxes, other than income taxes increased $19 million in 2020 compared with 2019 primarily due to higher property taxes ($37 million), higher state and local taxes ($1 million) and the absence in 2020 of a reduction in the sales and use tax reserve upon conclusion of the audit assessment ($1 million), offset in part by higher deferral of under-collected property taxes ($19 million) and lower payroll taxes ($1 million) due to the Employee Retention Tax Credit created under the CARES Act. See “Coronavirus Disease 2019 (COVID-19) Impacts - Impact of CARES Act and 2021 Appropriations Act on Accounting for Income Taxes,” above.

Steam

CECONY’s results of steam operations for the year ended December 31, 2020 compared with the year ended December 31, 2019 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	Variation
Operating revenues	$508	$627	$(119)
Purchased power	27	33	(6)
Fuel	81	108	(27)
Other operations and maintenance	161	177	(16)
Depreciation and amortization	90	89	1
Taxes, other than income taxes	144	158	(14)
Steam operating income	$5	$62	$(57)

CECONY’s steam sales and deliveries in 2020 compared with 2019 were:

	Millions of Pounds Delivered						Revenues in Millions
	For the Years Ended						For the Years Ended
Description	December 31, 2020	December 31, 2019	Variation	Percent Variation			December 31, 2020	December 31, 2019	Variation	Percent Variation
General	445	536	(91)	(17.0)	%		$23	$27	$(4)	(14.8)	%
Apartment house	5,131	5,919	(788)	(13.3)			136	160	(24)	(15.0)
Annual power	10,977	13,340	(2,363)	(17.7)			321	395	(74)	(18.7)
Other operating revenues (a)	—	—	—	—			28	45	(17)	(37.8)
Total	16,553	19,795	(3,242)	(16.4)	%	(b)	$508	$627	$(119)	(19.0)	%

(a)Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan. See Note B to the financial statements in Item 8.

(b)After adjusting for variations, primarily weather and billing days, steam sales and deliveries in the company’s service area decreased 6.7 percent in 2020 compared with 2019. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues decreased $119 million in 2020 compared with 2019 primarily due to the impact of warmer winter weather ($43 million), lower fuel expenses ($27 million), lower usage by customers due to the impact of the COVID-19 pandemic ($19 million), certain rate plan reconciliations ($15 million) and lower purchased power expenses ($6 million).

Purchased power expenses decreased $6 million in 2020 compared with 2019 due to lower unit costs ($3 million) and purchased volumes ($3 million).

64 CON EDISON ANNUAL REPORT 2020

Fuel expenses decreased $27 million in 2020 compared with 2019 due to lower unit costs ($14 million) and lower purchased volumes from the company’s steam generating facilities ($13 million).

Other operations and maintenance expenses decreased $16 million in 2020 compared with 2019 primarily due to lower costs for pension and other postretirement benefits ($7 million) and lower municipal infrastructure support costs ($7 million).

Depreciation and amortization increased $1 million in 2020 compared with 2019 primarily due to higher steam utility plant balances.

Taxes, other than income taxes decreased $14 million in 2020 compared with 2019 primarily due to higher deferral of under-collected property taxes ($20 million) and lower state and local taxes ($2 million), offset in part by higher property taxes ($8 million).

Taxes, Other Than Income Taxes

At $2,456 million, taxes other than income taxes remain one of CECONY’s largest operating expenses. The principal components of, and variations in, taxes other than income taxes were:

	For the Years Ended December 31,
(Millions of Dollars)	2020		2019		Variation
Property taxes	$2,129		$1,979		$150
State and local taxes related to revenue receipts	338		328		10
Payroll taxes	64		69		(5)
Other taxes	(75)		(81)		6
Total	$2,456	(a)	$2,295	(a)	$161

(a)Including sales tax on customers’ bills, total taxes other than income taxes in 2020 and 2019 were $2,989 and $2,807 million, respectively.

Other Income (Deductions)

Other income (deductions) decreased $136 million in 2020 compared with 2019 primarily due to higher costs associated with components of pension and other postretirement benefits other than service cost ($117 million) and the absence of the company’s share of gain on sale of properties in 2019 ($14 million).

Net Interest Expense

Net interest expense increased $11 million in 2020 compared with 2019 primarily due to higher interest on long-term debt ($46 million), offset in part by a decrease in interest accrued on the TCJA related regulatory liability ($13 million), lower interest expense for short-term debt ($12 million) and lower interest accrued on the system benefit charge liability ($8 million).

Income Tax Expense

Income taxes decreased $120 million in 2020 compared with 2019 primarily due to lower income before income tax expense ($39 million), an increase in the amortization of excess deferred federal income taxes due to CECONY’s electric and gas rate plans that went into effect in January 2020 ($103 million) and lower state income taxes ($13 million), offset in part by the absence of the amortization of excess deferred state income taxes in 2020 ($24 million), lower research and development credits in 2020 ($5 million) and lower flow-through tax benefits in 2020 for plant-related items ($4 million).

O&R

	For the Year Ended December 31, 2020			For the Year Ended December 31, 2019
(Millions of Dollars)	Electric	Gas	2020 Total	Electric	Gas	2019 Total	2020-2019 Variation
Operating revenues	$629	$233	$862	$634	$259	$893	$(31)
Purchased power	169	—	169	188	—	188	(19)
Gas purchased for resale	—	61	61	—	90	90	(29)
Other operations and maintenance	242	68	310	235	73	308	2
Depreciation and amortization	65	25	90	60	24	84	6
Taxes, other than income taxes	54	31	85	53	31	84	1
Operating income	$99	$48	$147	$98	$41	$139	$8

                                                                                                                         CON EDISON ANNUAL REPORT 2020 65

Electric

O&R’s results of electric operations for the year ended December 31, 2020 compared with the year ended December 31, 2019 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	Variation
Operating revenues	$629	$634	$(5)
Purchased power	169	188	(19)
Other operations and maintenance	242	235	7
Depreciation and amortization	65	60	5
Taxes, other than income taxes	54	53	1
Electric operating income	$99	$98	$1

O&R’s electric sales and deliveries in 2020 compared with 2019 were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Years Ended						For the Years Ended
Description	December 31, 2020	December 31, 2019	Variation	Percent Variation			December 31, 2020	December 31, 2019	Variation	Percent Variation
Residential/Religious (b)	1,786	1,703	83	4.9	%		$318	$309	$9	2.9	%
Commercial/Industrial	820	808	12	1.5			117	112	5	4.5
Retail choice customers	2,621	2,885	(264)	(9.2)			186	191	(5)	(2.6)
Public authorities	107	106	1	0.9			7	8	(1)	(12.5)
Other operating revenues (c)	—	—	—	—			1	14	(13)	(92.9)
Total	5,334	5,502	(168)	(3.1)	%	(d)	$629	$634	$(5)	(0.8)	%

(a)Revenues from New York electric delivery sales are subject to a revenue decoupling mechanism, as a result of which, delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. 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 the revenue decoupling mechanism current asset or regulatory liability in accordance with the company’s New York electric rate plan and changes in regulatory assets and liabilities in accordance with the company’s electric rate plans. See Note B to the financial statements in Item 8.

(d)After adjusting for weather and other variations, electric delivery volumes in company’s service area decreased 0.7 percent in 2020 compared with 2019. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues decreased $5 million in 2020 compared with 2019 primarily due to lower purchased power expenses ($19 million), offset in part by higher revenues from the New York electric rate plan ($16 million).

Purchased power expenses decreased $19 million in 2020 compared with 2019 due to lower unit costs.

Other operations and maintenance expenses increased $7 million in 2020 compared with 2019 primarily due to the amortization of prior deferred storm costs ($3 million) and food and medicine spoilage claims related to outages caused by Tropical Storm Isaias ($3 million).

Depreciation and amortization increased $5 million in 2020 compared with 2019 primarily due to higher electric utility plant balances.

Taxes, other than income taxes increased $1 million in 2020 compared with 2019 primarily due to higher property taxes ($2 million), offset in part by lower payroll taxes ($1 million).

Gas

O&R’s results of gas operations for the year ended December 31, 2020 compared with the year ended December 31, 2019 were as follows:

66 CON EDISON ANNUAL REPORT 2020

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	Variation
Operating revenues	$233	$259	$(26)
Gas purchased for resale	61	90	(29)
Other operations and maintenance	68	73	(5)
Depreciation and amortization	25	24	1
Taxes, other than income taxes	31	31	—
Gas operating income	$48	$41	$7

O&R’s gas sales and deliveries, excluding off-system sales, in 2020 compared with 2019 were:

	Thousands of Dt Delivered						Revenues in Millions (a)
	For the Years Ended						For the Years Ended
Description	December 31, 2020	December 31, 2019	Variation	Percent Variation			December 31, 2020	December 31, 2019	Variation	Percent Variation
Residential	9,736	10,209	(473)	(4.6)	%		$121	$136	$(15)	(11.0)	%
General	2,142	2,328	(186)	(8.0)			20	25	(5)	(20.0)
Firm transportation	8,271	9,459	(1,188)	(12.6)			62	63	(1)	(1.6)
Total firm sales and transportation	20,149	21,996	(1,847)	(8.4)		(b)	203	224	(21)	(9.4)
Interruptible sales	3,632	3,668	(36)	(1.0)			6	6	—	—
Generation plants	59	4	55	Large			—	—	—	—
Other	658	914	(256)	(28.0)			1	1	—	—
Other gas revenues	—	—	—	—			23	28	(5)	(17.9)
Total	24,498	26,582	(2,084)	(7.8)	%		$233	$259	$(26)	(10.0)	%

(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, firm sales and transportation volumes in the company’s service area increased 0.6 percent in 2020 compared with 2019. See “Coronavirus Disease 2019 (COVID-19) Impacts,” above.

Operating revenues decreased $26 million in 2020 compared with 2019 primarily due to lower gas purchased for resale expense.

Gas purchased for resale decreased $29 million in 2020 compared with 2019 due to lower unit costs ($24 million) and purchased volumes ($5 million).

Other operations and maintenance expenses decreased $5 million in 2020 compared with 2019 primarily due to lower pension costs.

Depreciation and amortization increased $1 million in 2020 compared with 2019 primarily due to higher gas utility plant balances.

Taxes, Other Than Income Taxes

Taxes, other than income taxes, increased $1 million in 2020 compared with 2019. The principal components of taxes, other than income taxes, were:

	For the Years Ended December 31,
(Millions of Dollars)	2020		2019		Variation
Property taxes	$69		$66		$3
State and local taxes related to revenue receipts	10		10		—
Payroll taxes	6		8		(2)
Total	$85	(a)	$84	(a)	$1

(a)Including sales tax on customers’ bills, total taxes other than income taxes in 2020 and 2019 were $121 million and $116 million, respectively.

Income Tax Expense

Income taxes increased $4 million in 2020 compared with 2019 primarily due to higher income before income tax expense ($1 million), higher state income taxes ($1 million), lower flow-through tax benefits on plant-related items in 2020 ($1 million), and an increase in flow-through income tax expense on higher bad debt reserves in 2020 as compared with 2019 ($1 million).

                                                                                                                         CON EDISON ANNUAL REPORT 2020 67

Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the year ended December 31, 2020 compared with the year ended December 31, 2019 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	Variation
Operating revenues	$736	$857	$(121)
Gas purchased for resale	41	185	(144)
Other operations and maintenance	228	223	5
Depreciation and amortization	231	226	5
Taxes, other than income taxes	21	21	—
Operating income	$215	$202	$13

Operating revenues decreased $121 million in 2020 compared with 2019 primarily due to lower wholesale revenues ($136 million) and lower energy services revenues ($19 million), offset in part by higher renewable electric production revenues ($34 million).

Gas purchased for resale decreased $144 million in 2020 compared with 2019 primarily due to lower purchased volumes.

Other operations and maintenance expenses increased $5 million in 2020 compared with 2019 primarily due to an increase in general operating expenses.

Depreciation and amortization increased $5 million in 2020 compared with 2019 primarily due to an increase in renewable electric production projects in operation during 2020.

Net Interest Expense

Net interest expense increased $10 million in 2020 compared with 2019 primarily due to higher unrealized losses on interest rate swaps in the 2020 period.

Income Tax Expense

Income taxes increased $14 million in 2020 compared with 2019 primarily due to higher income before income tax expense ($1 million), lower income attributable to non-controlling interest ($13 million), and the absence of the adjustment for prior period federal income tax returns primarily due to higher research and development credits in 2019 ($13 million), offset in part by a tax benefit 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 ($4 million), a lower increase in uncertain tax position ($7 million) and higher renewable energy credits ($2 million).

Income Attributable to Non-Controlling Interest

Income attributable to non-controlling interest increased $54 million in 2020 compared with 2019 primarily due to lower losses attributable in the 2020 period to a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. See Note R to the financial statements in Item 8.

Con Edison Transmission

Net Interest Expense

Net interest expense decreased $7 million in 2020 compared with 2019 primarily due to a reduction to short-term borrowings and rates charged under an intercompany capital funding facility.

Other Income (Deductions)

Other income (deductions) decreased $319 million in 2020 compared with 2019 primarily due to an impairment loss related to Con Edison Transmission's investment in Mountain Valley Pipeline, LLC. See "Application of Critical Account Policies - Investments" in Item 7 and "Investments" in Note A to the financial statement in Item 8.

Income Tax Expense

Income taxes decreased $87 million in 2020 compared with 2019 primarily due to the MVP impairment loss recorded in 2020 ($88 million).

68 CON EDISON ANNUAL REPORT 2020

Other

Taxes, Other Than Income Taxes

Taxes, other than income taxes increased $7 million in 2020 compared with 2019 primarily due to adjustments made to the New York City capital tax for prior periods in the 2020 period.

Other Income (Deductions)

Other income (deductions) increased $7 million in 2020 compared with 2019 primarily due to the absence in 2020 of an elimination related to interest income under the intercompany capital funding facility.

Income Tax Expense

Income taxes decreased $17 million in 2020 compared with 2019 primarily due to lower income before income tax expense ($3 million), the reversal of a portion of a New York City valuation allowance ($9 million), and the MVP impairment loss recorded in 2020 ($9 million), offset in part by lower consolidated state income tax benefits ($4 million).

During the fourth quarter of 2020, Con Edison reversed a portion of its valuation allowance that was recorded against the deferred tax asset established for the New York City NOL. Management has reassessed its ability to realize a portion of the deferred tax benefits generated primarily by its renewable energy projects due to the future reversal of temporary differences associated with the accelerated tax depreciation and by implementing its strategy to secure tax equity financing from third parties for which certain tax deductions and amortization will be specifically allocated to members outside of the consolidated group.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 69

Year Ended December 31, 2019 Compared with Year Ended December 31, 2018

CECONY

	For the Year Ended December 31, 2019				For the Year Ended December 31, 2018
(Millions of Dollars)	Electric	Gas	Steam	2019 Total	Electric	Gas	Steam	2018 Total	2019-2018 Variation
Operating revenues	$8,062	$2,132	$627	$10,821	$7,971	$2,078	$631	$10,680	$141
Purchased power	1,324	—	33	1,357	1,393	—	40	1,433	(76)
Fuel	99	—	108	207	158	—	105	263	(56)
Gas purchased for resale	—	606	—	606	—	643	—	643	(37)
Other operations and maintenance	2,059	399	177	2,635	1,961	420	174	2,555	80
Depreciation and amortization	1,053	231	89	1,373	984	205	87	1,276	97
Taxes, other than income taxes	1,769	368	158	2,295	1,676	332	148	2,156	139
Operating income	$1,758	$528	$62	$2,348	$1,799	$478	$77	$2,354	$(6)

Electric

CECONY’s results of electric operations for the year ended December 31, 2019 compared with the year ended December 31, 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019	2018	Variation
Operating revenues	$8,062	$7,971	$91
Purchased power	1,324	1,393	(69)
Fuel	99	158	(59)
Other operations and maintenance	2,059	1,961	98
Depreciation and amortization	1,053	984	69
Taxes, other than income taxes	1,769	1,676	93
Electric operating income	$1,758	$1,799	$(41)

CECONY’s electric sales and deliveries in 2019 compared with 2018 were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Years Ended						For the Years Ended
Description	December 31, 2019	December 31, 2018	Variation	Percent Variation			December 31, 2019	December 31, 2018	Variation	Percent Variation
Residential/Religious (b)	10,560	10,797	(237)	(2.2)	%		$2,671	$2,846	$(175)	(6.1)	%
Commercial/Industrial	9,908	9,588	320	3.3			1,845	1,850	(5)	(0.3)
Retail choice customers	24,754	26,266	(1,512)	(5.8)			2,470	2,624	(154)	(5.9)
NYPA, Municipal Agency and other sales	9,932	10,186	(254)	(2.5)			663	662	1	0.2
Other operating revenues (c)	—	—	—	—			413	(11)	424	Large
Total	55,154	56,837	(1,683)	(3.0)	%	(d)	$8,062	$7,971	$91	1.1	%

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

(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 plan.

(d)After adjusting for variations, primarily weather and billing days, electric delivery volumes in the company’s service area decreased 1.1 percent in 2019 compared with 2018.

Operating revenues increased $91 million in 2019 compared with 2018 primarily due to an increase in revenues from the rate plan ($215 million), including earnings adjustment mechanism incentives for energy efficiency ($22 million), offset in part by lower purchased power expenses ($69 million) and fuel expenses ($59 million).

Purchased power expenses decreased $69 million in 2019 compared with 2018 due to lower unit costs ($199 million), offset in part by higher purchased volumes ($130 million).

70 CON EDISON ANNUAL REPORT 2020

Fuel expenses decreased $59 million in 2019 compared with 2018 due to lower unit costs ($54 million) and purchased volumes from the company’s electric generating facilities ($5 million).

Other operations and maintenance expenses increased $98 million in 2019 compared with 2018 primarily due to higher costs for pension and other postretirement benefits ($91 million), surcharges for assessments and fees that are collected in revenues from customers ($40 million) and higher stock-based compensation ($23 million), offset in part by lower other employee benefits ($41 million) and municipal infrastructure support costs ($12 million).

Depreciation and amortization increased $69 million in 2019 compared with 2018 primarily due to higher electric utility plant balances.

Taxes, other than income taxes increased $93 million in 2019 compared with 2018 primarily due to higher property taxes ($86 million) and the absence of a New York State sales and use tax refund received in 2018 ($26 million), offset in part by higher deferral of under-collected property taxes ($11 million), the reduction in the sales and use tax reserve upon conclusion of an audit assessment ($6 million) and lower state and local taxes ($2 million).

Gas

CECONY’s results of gas operations for the year ended December 31, 2019 compared with the year ended December 31, 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019	2018	Variation
Operating revenues	$2,132	$2,078	$54
Gas purchased for resale	606	643	(37)
Other operations and maintenance	399	420	(21)
Depreciation and amortization	231	205	26
Taxes, other than income taxes	368	332	36
Gas operating income	$528	$478	$50

CECONY’s gas sales and deliveries, excluding off-system sales, in 2019 compared with 2018 were:

	Thousands of Dt Delivered						Revenues in Millions (a)
	For the Years Ended						For the Years Ended
Description	December 31, 2019	December 31, 2018	Variation	Percent Variation			December 31, 2019	December 31, 2018	Variation	Percent Variation
Residential	54,402	57,815	(3,413)	(5.9)	%		$943	$966	$(23)	(2.4)	%
General	33,235	34,490	(1,255)	(3.6)			384	390	(6)	(1.5)
Firm transportation	81,710	82,472	(762)	(0.9)			593	595	(2)	(0.3)
Total firm sales and transportation	169,347	174,777	(5,430)	(3.1)		(b)	1,920	1,951	(31)	(1.6)
Interruptible sales (c)	9,903	7,351	2,552	34.7			42	40	2	5.0
NYPA	39,643	34,079	5,564	16.3			2	2	—	—
Generation plants	52,011	72,524	(20,513)	(28.3)			23	26	(3)	(11.5)
Other	20,701	20,822	(121)	(0.6)			31	31	—	—
Other operating revenues (d)	—	—	—	—			114	28	86	Large
Total	291,605	309,553	(17,948)	(5.8)	%		$2,132	$2,078	$54	2.6	%

(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 increased 1.8 percent in 2019 compared with 2018, reflecting primarily increased volumes attributable to the growth in the number of gas customers.

(c)Includes 5,484 thousands and 3,326 thousands of Dt for 2019 and 2018, 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. See Note B to the financial statements in Item 8.

Operating revenues increased $54 million in 2019 compared with 2018 primarily due to an increase in revenues from the rate plan ($99 million), offset in part by lower gas purchased for resale expense ($37 million).

                                                                                                                         CON EDISON ANNUAL REPORT 2020 71

Gas purchased for resale decreased $37 million in 2019 compared with 2018 due to lower unit costs ($34 million) and purchased volumes ($3 million).

Other operations and maintenance expenses decreased $21 million in 2019 compared with 2018 primarily due to lower surcharges for assessments and fees that are collected in revenues from customers.

Depreciation and amortization increased $26 million in 2019 compared with 2018 primarily due to higher gas utility plant balances.

Taxes, other than income taxes increased $36 million in 2019 compared with 2018 primarily due to higher property taxes ($37 million), the absence of a New York State sales and use tax refund received in 2018 ($3 million) and higher state and local taxes ($2 million), offset in part by higher deferral of under-collected property taxes ($4 million) and the reduction in the sales and use tax reserve upon conclusion of an audit assessment ($1 million).

Steam

CECONY’s results of steam operations for the year ended December 31, 2019 compared with the year ended December 31, 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019	2018	Variation
Operating revenues	$627	$631	$(4)
Purchased power	33	40	(7)
Fuel	108	105	3
Other operations and maintenance	177	174	3
Depreciation and amortization	89	87	2
Taxes, other than income taxes	158	148	10
Steam operating income	$62	$77	$(15)

CECONY’s steam sales and deliveries in 2019 compared with 2018 were:

	Millions of Pounds Delivered						Revenues in Millions
	For the Years Ended						For the Years Ended
Description	December 31, 2019	December 31, 2018	Variation	Percent Variation			December 31, 2019	December 31, 2018	Variation	Percent Variation
General	536	593	(57)	(9.6)	%		$27	$30	$(3)	(10.0)	%
Apartment house	5,919	6,358	(439)	(6.9)			160	174	(14)	(8.0)
Annual power	13,340	14,811	(1,471)	(9.9)			395	441	(46)	(10.4)
Other operating revenues (a)	—	—	—	—			45	(14)	59	Large
Total	19,795	21,762	(1,967)	(9.0)	%	(b)	$627	$631	$(4)	(0.6)	%

(a)Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan. See Note B to the financial statements in Item 8.

(b)After adjusting for variations, primarily weather and billing days, steam sales and deliveries in the company’s service area decreased 4.4 percent in 2019 compared with 2018.

Operating revenues decreased $4 million in 2019 compared with 2018 primarily due to the impact of warmer winter weather ($26 million) and lower purchased power expenses ($7 million), offset by certain rate plan reconciliations ($16 million), lower reserve related to steam earnings sharing ($14 million) and higher fuel expenses ($3 million).

Purchased power expenses decreased $7 million in 2019 compared with 2018 due to lower unit costs ($6 million) and purchased volumes ($1 million).

Fuel expenses increased $3 million in 2019 compared with 2018 due to higher unit costs ($7 million), offset in part by lower purchased volumes from the company’s steam generating facilities ($4 million).

Other operations and maintenance expenses increased $3 million in 2019 compared with 2018 primarily due to higher municipal infrastructure support costs ($7 million), higher costs for pension and other postretirement benefits ($8 million) and stock-based compensation ($2 million), offset in part by the absence in 2019 of property damage, clean-up and other response costs related to a steam main rupture in 2018 ($11 million).

72 CON EDISON ANNUAL REPORT 2020

Depreciation and amortization increased $2 million in 2019 compared with 2018 primarily due to higher steam utility plant balances.

Taxes, other than income taxes increased $10 million in 2019 compared with 2018 primarily due to higher property taxes ($12 million) and the absence of a New York State sales and use tax refund received in 2018 ($1 million), offset in part by lower state and local taxes ($1 million), higher deferral of under-collected property taxes ($1 million) and the reduction in the sales and use tax reserve upon conclusion of an audit assessment ($1 million).

Taxes, Other Than Income Taxes

At $2,295 million, taxes other than income taxes remain one of CECONY’s largest operating expenses. The principal components of, and variations in, taxes other than income taxes were:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		Variation
Property taxes	$1,979		$1,845		$134
State and local taxes related to revenue receipts	328		330		(2)
Payroll taxes	69		69		—
Other taxes	(81)		(88)		7
Total	$2,295	(a)	$2,156	(a)	$139

(a)Including sales tax on customers’ bills, total taxes other than income taxes in 2019 and 2018 were $2,807 and $2,628 million, respectively.

Other Income (Deductions)

Other income (deductions) increased $108 million in 2019 compared with 2018 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 $39 million in 2019 compared with 2018 primarily due to higher interest expense for long-term ($10 million) and short-term ($6 million) debt, an increase in interest accrued on the TCJA related regulatory liability ($9 million) and interest accrued on the system benefit charge liability ($8 million).

Income Tax Expense

Income taxes increased $9 million in 2019 compared with 2018 primarily due to higher income before income tax expense ($13 million) and lower tax benefits in 2019 for plant-related flow through items ($7 million), offset in part by an increase in the amortization of excess deferred federal income taxes due to the TCJA ($11 million).

O&R

	For the Year Ended December 31, 2019			For the Year Ended December 31, 2018
(Millions of Dollars)	Electric	Gas	2019 Total	Electric	Gas	2018 Total	2019-2018 Variation
Operating revenues	$634	$259	$893	$642	$249	$891	$2
Purchased power	188	—	188	208	—	208	(20)
Gas purchased for resale	—	90	90	—	86	86	4
Other operations and maintenance	235	73	308	233	72	305	3
Depreciation and amortization	60	24	84	56	21	77	7
Taxes, other than income taxes	53	31	84	52	31	83	1
Operating income	$98	$41	$139	$93	$39	$132	$7

                                                                                                                         CON EDISON ANNUAL REPORT 2020 73

Electric

O&R’s results of electric operations for the year ended December 31, 2019 compared with the year ended December 31, 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019	2018	Variation
Operating revenues	$634	$642	$(8)
Purchased power	188	208	(20)
Other operations and maintenance	235	233	2
Depreciation and amortization	60	56	4
Taxes, other than income taxes	53	52	1
Electric operating income	$98	$93	$5

O&R’s electric sales and deliveries in 2019 compared with 2018 were:

	Millions of kWh Delivered						Revenues in Millions (a)
	For the Years Ended						For the Years Ended
Description	December 31, 2019	December 31, 2018	Variation	Percent Variation			December 31, 2019	December 31, 2018	Variation	Percent Variation
Residential/Religious (b)	1,703	1,713	(10)	(0.6)	%		$309	$326	$(17)	(5.2)	%
Commercial/Industrial	808	799	9	1.1			112	115	(3)	(2.6)
Retail choice customers	2,885	2,974	(89)	(3.0)			191	201	(10)	(5.0)
Public authorities	106	131	(25)	(19.1)			8	12	(4)	(33.3)
Other operating revenues (c)	—	—	—	—			14	(12)	26	Large
Total	5,502	5,617	(115)	(2.0)	%	(d)	$634	$642	$(8)	(1.2)	%

(a)Revenues from New York electric delivery sales are subject to a revenue decoupling mechanism, as a result of which, delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. 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 the revenue decoupling mechanism current asset or regulatory liability in accordance with the company’s New York electric rate plan and changes in regulatory assets and liabilities in accordance with the company’s electric rate plans. See Note B to the financial statements in Item 8.

(d)After adjusting for weather and other variations, electric delivery volumes in company’s service area decreased 1.1 percent in 2019 compared with 2018.

Operating revenues decreased $8 million in 2019 compared with 2018 primarily due to lower purchased power expenses.

Purchased power expenses decreased $20 million in 2019 compared with 2018 due to lower unit costs ($21 million), offset in part by higher purchased volumes ($1 million).

Other operations and maintenance expenses increased $2 million in 2019 compared with 2018 primarily due to a regulatory change in accounting for manufactured gas plant spending ($5 million) and higher stock-based compensation ($2 million), offset in part by the reduction of a regulatory asset associated with certain site investigation and remediation costs in 2018 ($6 million).

Depreciation and amortization increased $4 million in 2019 compared with 2018 primarily due to higher electric utility plant balances.

Taxes, other than income taxes increased $1 million in 2019 compared with 2018 primarily due to higher property taxes.

Gas

O&R’s results of gas operations for the year ended December 31, 2019 compared with the year ended December 31, 2018 were as follows:

74 CON EDISON ANNUAL REPORT 2020

	For the Years Ended December 31,
(Millions of Dollars)	2019	2018	Variation
Operating revenues	$259	$249	$10
Gas purchased for resale	90	86	4
Other operations and maintenance	73	72	1
Depreciation and amortization	24	21	3
Taxes, other than income taxes	31	31	—
Gas operating income	$41	$39	$2

O&R’s gas sales and deliveries, excluding off-system sales, in 2019 compared with 2018 were:

	Thousands of Dt Delivered						Revenues in Millions (a)
	For the Years Ended						For the Years Ended
Description	December 31, 2019	December 31, 2018	Variation	Percent Variation			December 31, 2019	December 31, 2018	Variation	Percent Variation
Residential	10,209	9,860	349	3.5	%		$136	$140	$(4)	(2.9)	%
General	2,328	2,190	138	6.3			25	26	(1)	(3.8)
Firm transportation	9,459	9,950	(491)	(4.9)			63	78	(15)	(19.2)
Total firm sales and transportation	21,996	22,000	(4)	—		(b)	224	244	(20)	(8.2)
Interruptible sales	3,668	3,746	(78)	(2.1)			6	6	—	—
Generation plants	4	1	3	Large			—	—	—	—
Other	914	959	(45)	(4.7)			1	1	—	—
Other gas revenues	—	—	—	—			28	(2)	30	Large
Total	26,582	26,706	(124)	(0.5)	%		$259	$249	$10	4.0	%

(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, firm sales and transportation volumes in the company’s service area increased 0.9 percent in 2019 compared with 2018.

Operating revenues increased $10 million in 2019 compared with 2018 primarily due to higher revenues from the New York gas rate plan ($8 million) and an increase in gas purchased for resale ($4 million).

Gas purchased for resale increased $4 million in 2019 compared with 2018 due to higher unit costs ($3 million) and purchased volumes ($1 million).

Other operations and maintenance expenses increased $1 million in 2019 compared with 2018 primarily due to a regulatory change in accounting for manufactured gas plant spending ($3 million) and higher stock-based compensation ($1 million), offset in part by the reduction of a regulatory asset associated with certain site investigation and remediation costs in 2018 ($3 million).

Depreciation and amortization increased $3 million in 2019 compared with 2018 primarily due to higher gas utility plant balances.

Taxes, Other Than Income Taxes

Taxes, other than income taxes, increased $1 million in 2019 compared with 2018. The principal components of taxes, other than income taxes, were:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		Variation
Property taxes	$66		$65		$1
State and local taxes related to revenue receipts	10		10		—
Payroll taxes	8		8		—
Total	$84	(a)	$83	(a)	$1

(a)Including sales tax on customers’ bills, total taxes other than income taxes in 2019 and 2018 were $116 million and $112 million, respectively.

Other Income (Deductions)

                                                                                                                         CON EDISON ANNUAL REPORT 2020 75

Other income (deductions) increased $8 million in 2019 compared with 2018 primarily due to lower costs associated with components of pension and other postretirement benefits other than service cost.

Income Tax Expense

Income taxes increased $2 million in 2019 compared with 2018 primarily due to higher income before income tax expense ($3 million), offset in part by an increase in amortization of excess deferred federal income taxes due to the TCJA ($1 million).

Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the year ended December 31, 2019 compared with the year ended December 31, 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019	2018	Variation
Operating revenues	$857	$763	$94
Purchased power	—	2	(2)
Gas purchased for resale	185	313	(128)
Other operations and maintenance	223	287	(64)
Depreciation and amortization	226	85	141
Taxes, other than income taxes	21	13	8
Gain on acquisition of Sempra Solar Holdings, LLC (a)	—	131	(131)
Operating income	$202	$194	$8

(a) See Note V to the financial statements in Item 8.

Operating revenues increased $94 million in 2019 compared with 2018 primarily due to higher revenues from renewable electric production projects resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC, including the consolidation of certain jointly-owned projects that were previously accounted for as equity investments ($340 million), offset in part by lower wholesale revenues ($144 million), lower engineering, procurement and construction services revenues due to the completion in 2018 of a solar electric production project developed for another company ($92 million) and lower energy services revenues ($24 million). Net mark-to-market values increased ($14 million).

Purchased power expenses decreased $2 million in 2019 compared with 2018 primarily due to the absence in the 2019 period of the true-ups relating to the retail electric supply business sold in 2016.

Gas purchased for resale decreased $128 million in 2019 compared with 2018 due to lower purchased volumes.

Other operations and maintenance expenses decreased $64 million in 2019 compared with 2018 primarily due to lower engineering, procurement and construction costs ($82 million) and lower energy services costs ($18 million), offset in part by higher costs associated with additional renewable electric production projects in operation resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC ($26 million).

Depreciation and amortization increased $141 million in 2019 compared with 2018 primarily due to an increase in renewable electric production projects resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC (including the consolidation of certain jointly-owned projects that the Clean Energy Businesses previously accounted for as equity method investments).

Taxes, other than income taxes increased $8 million in 2019 compared with 2018 primarily due to higher property taxes associated with additional renewable electric production projects in operation resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC.

Gain on acquisition of Sempra Solar Holdings, LLC decreased $131 million in 2019 compared with 2018 due to the absence in 2019 of the gain recognized in 2018 with respect to jointly-owned renewable energy production projects upon completion of the acquisition of Sempra Solar Holdings, LLC. See Note V to the financial statements in Item 8.

Other Income (Deductions)

Other income (deductions) decreased $28 million in 2019 compared with 2018 primarily due to the absence in 2019 of equity income from certain jointly-owned projects that were accounted for as equity investments in 2018 but consolidated after the December 2018 acquisition of Sempra Solar Holdings, LLC.

76 CON EDISON ANNUAL REPORT 2020

Net Interest Expense

Net interest expense increased $123 million in 2019 compared with 2018 primarily due to an increase in debt resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC, including $825 million that was borrowed to fund a portion of the purchase price, $576 million of Sempra Solar Holdings, LLC subsidiaries' project debt that was outstanding at the time of the acquisition and the consolidation of $506 million of project debt of certain jointly-owned projects that the Clean Energy Businesses previously accounted for as equity method investments.

Income Tax Expense

Income taxes decreased $77 million in 2019 compared with 2018 primarily due to lower income before income tax expense (excluding income attributable to non-controlling interest) ($50 million), higher renewable energy credits ($7 million), lower state income taxes ($11 million), adjustments for prior period federal income tax returns primarily due to increased research and development credits ($11 million) and lower valuation allowances on state net operating losses ($6 million), offset in part by an increase in uncertain tax positions ($9 million).

Income Attributable to Non-Controlling Interest

Income attributable to non-controlling interest increased $97 million in 2019 compared with 2018 primarily due to the income attributable in the 2019 period to a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. See Note R to the financial statements in Item 8.

Con Edison Transmission

Other Income (Deductions)

Other income (deductions) increased $13 million in 2019 compared with 2018 primarily due to higher allowance for funds used during construction from the Mountain Valley Pipeline, LLC ($27 million), offset in part by lower contract renewal rates at Stagecoach Gas Services, LLC ($17 million). See “Con Edison Transmission - CET Gas” in Item 1.

Net Interest Expense

Net interest expense increased $5 million in 2019 compared with 2018 primarily due to funding of increased investment in Mountain Valley Pipeline, LLC.

Income Tax Expense

Income taxes increased $4 million in 2019 compared with 2018 primarily due to higher income before income tax expense ($2 million) and a decrease in the amortization of excess deferred federal income taxes due to the TCJA ($1 million).

Other

Taxes, Other Than Income Taxes

Taxes, other than income taxes decreased $8 million in 2019 compared with 2018 primarily due to lower New York State capital tax.

Other Income (Deductions)

Other income (deductions) increased $12 million in 2019 compared with 2018 primarily due to the absence in 2019 of transaction costs related to the acquisition of Sempra Solar Holdings, LLC in 2018. See Note V to the financial statements in Item 8.

Income Tax Expense

Income taxes decreased $43 million in 2019 compared with 2018 primarily due to the absence of the TCJA re-measurement of deferred tax assets associated with Con Edison’s 2017 net operating loss carryforward into 2018.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 77

Liquidity and Capital Resources

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

The principal factors affecting Con Edison’s liquidity are its investments in the Utilities, the Clean Energy Businesses and Con Edison Transmission, the dividends it pays to its shareholders and the dividends it receives from the Utilities and cash flows from financing activities discussed below.

The principal factors affecting CECONY’s liquidity are its cash flows from operating activities, cash used in investing activities (including construction expenditures), the dividends it pays to Con Edison and cash flows from financing activities discussed below.

The Companies generally maintain minimal cash balances and use short-term borrowings to meet their working capital needs and other cash requirements. The Companies repay their short-term borrowings using funds from long-term financings and operating activities. The Utilities’ cost of capital, including working capital, is reflected in the rates they charge to their customers.

Each of the Companies believes that it will be able to meet its reasonably likely short-term and long-term cash requirements. See “The Companies Require Access To Capital Markets To Satisfy Funding Requirements,” "Changes To Tax Laws Could Adversely Affect the Companies," “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” in Item 1A, and “Capital Requirements and Resources” in Item 1.

78 CON EDISON ANNUAL REPORT 2020

The Companies’ cash, temporary cash investments and restricted cash resulting from operating, investing and financing activities for the years ended December 31, 2020, 2019 and 2018 are summarized as follows:

	CECONY			O&R			Clean Energy Businesses			Con Edison Transmission			Other (a)			Con Edison (b)
(Millions of Dollars)	2020	2019	2018	2020	2019	2018	2020	2019	2018	2020	2019	2018	2020	2019	2018	2020	2019	2018
Operating activities	$1,693	$2,502	$2,204	$146	$190	$172	$887	$199	$220	$(7)	$194	$87	$(521)	$49	$12	$2,198	$3,134	$2,695
Investing activities	(3,416)	(3,124)	(3,306)	(220)	(218)	(198)	(606)	(258)	(1,740)	18	(184)	(227)	—	2	—	(4,224)	(3,782)	(5,471)
Financing activities	1,857	737	1,190	79	8	31	(345)	184	1,590	(11)	(12)	140	665	(58)	(13)	2,245	859	2,938
Net change for the period	134	115	88	5	(20)	5	(64)	125	70	—	(2)	—	144	(7)	(1)	219	211	162
Balance at beginning of period	933	818	730	32	52	47	251	126	56	—	2	2	1	8	9	1,217	1,006	844
Balance at end of period (c)	$1,067	$933	$818	$37	$32	$52	$187	$251	$126	$—	$—	$2	$145	$1	$8	$1,436	$1,217	$1,006

(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 financial statements in Item 8.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 79

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. See "Competition" and "Environmental Matters – Clean Energy Future – Reforming the Energy Vision" and “Environmental Matters – Climate Change” in Item 1. During 2020, the decline in business activity in the Utilities’ service territory due to the COVID-19 pandemic resulted and may continue in 2021 to result in lower billed sales revenues, 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 generally not net income. The prices at which the Utilities provide energy to their customers are determined in accordance with their rate plans. 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. See “Recoverable Energy Costs” in Note A to the financial statements in Item 8. 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 “Changes To Tax Laws Could Adversely Affect the Companies,” in Item 1A, “Federal Income Tax” in Note A, “Rate Plans” in Note B, "COVID-19 Regulatory Matters" in Note B, “Other Regulatory Matters” in Note B and Note L to the financial statements in Item 8 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. See “Rate Plans – CECONY– Electric and Gas" and "Rate Plans – O&R New York – Electric and Gas” in Note B to the financial statements in Item 8. For Con Edison, 2020 net income also included a non-cash loss recognized with respect to a partial impairment of Con Edison Transmission’s investment in Mountain Valley Pipeline, LLC. See “Investments” in Note A to the financial statements in Item 8. For Con Edison, 2018 net income included a non-cash gain recognized with respect to jointly-owned renewable energy production projects upon completion of the acquisition of Sempra Solar Holdings, LLC at the Clean Energy Businesses ($131 million). See Note V to the financial statements in Item 8.

Net cash flows from operating activities in 2020 for Con Edison and CECONY were $936 million and $809 million lower, respectively, than in 2019. The changes in net cash flows for Con Edison and CECONY primarily reflects higher accounts receivable balances from customers ($566 million and $519 million, respectively) (see “COVID-19 Regulatory Matters” in Note B to the financial statements in Item 8 and “Coronavirus Disease 2019 (COVID-19) Impacts - Accounting Considerations” and “Liquidity and Financing,” above) and higher other receivables and other current assets ($188 million and $103 million, respectively) primarily due to lower reimbursement received for restoration costs related to the restoration of power in Puerto Rico in the aftermath of the September 2017 hurricanes in the 2020 period ($94 million and $88 million, respectively), higher system benefit charge ($139 million and $130 million, respectively), higher pension and retiree benefit contributions ($121 million and $113 million, respectively), deferrals for increased costs related to the COVID-19 pandemic ($115 million and $113 million, respectively), and a change in pension and retiree benefit obligations ($72 million and $77 million, respectively), offset in part by lower TCJA net benefits provided to customers in the 2020 period ($263 million and $263 million, respectively).

Net cash flows from operating activities in 2019 for Con Edison and CECONY were $439 million and $298 million higher, respectively, than in 2018. The changes in net cash flows for Con Edison and CECONY primarily reflects lower pension and retiree benefit contributions ($122 million and $115 million, respectively), lower storm restoration costs ($192 million and $132 million, respectively), lower MTA power reliability costs ($160 million and $160 million, respectively), reimbursement received for restoration costs related to the restoration of power in Puerto Rico in the aftermath of the September 2017 hurricanes ($95 million and $89 million, respectively), and for CECONY, lower net

80 CON EDISON ANNUAL REPORT 2020

payments of income tax to affiliated companies ($122 million), offset in part by higher TCJA net benefits provided to customers in the 2019 period ($379 million and $376 million, respectively).

The change in net cash flows also reflects the timing of payments for and recovery of energy costs. This timing is reflected within changes to accounts receivable – customers, recoverable 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 $442 million and $292 million higher, respectively, in 2020 than in 2019. The change for Con Edison primarily reflects an increase in non-utility construction expenditures at the Clean Energy Businesses ($335 million), the absence in 2020 of proceeds from the sale of properties formerly used by CECONY in its operations ($192 million), an increase in utility construction expenditures at CECONY ($84 million) and O&R ($4 million) and higher cost of removal less salvage at CECONY ($16 million), offset in part by lower investments in electric and gas transmission projects at Con Edison Transmission in the 2020 period ($202 million).

Net cash flows used in investing activities for Con Edison and CECONY were $1,689 million and $182 million lower, respectively, in 2019 than in 2018. The change for Con Edison primarily reflects the acquisition of Sempra Solar Holdings, LLC, net of cash acquired, at the Clean Energy Businesses in 2018 ($1,488 million) (see Note V to the financial statements in Item 8) and proceeds received in 2019 from the sale of properties formerly used by CECONY in its operations ($187 million).

Cash Flows From Financing Activities

Net cash flows from financing activities in 2020 for Con Edison and CECONY were $1,386 million and $1,120 million higher, respectively, than in 2019. Net cash flows from financing activities in 2019 for Con Edison and CECONY were $2,079 million and $453 million lower, respectively, than in 2018.

Net cash flows from financing activities during the years ended December 31, 2020, 2019 and 2018 reflect the following Con Edison transactions:

2020

•Issued 1,050,000 shares of its common shares for $88 million upon physical settlement of the remaining shares subject to its May 2019 forward sale agreement. Con Edison used the proceeds to invest in CECONY for funding of its capital requirements and other general corporate purposes. See Note C to the financial statements in Item 8;

•Borrowed $820 million pursuant to a credit agreement that was converted to a term loan (the “July 2020 Term Loan”). Con Edison used the proceeds from the borrowing for general corporate purposes, including repayment of short-term debt bearing interest at variable rates. The July 2020 Term Loan was prepaid in full in December 2020;

•Issued 7,200,000 common shares resulting in net proceeds of $553 million, after issuance expenses. The net proceeds from the sale of the common shares, together with the net proceeds from the sale of $650 million aggregate principal amount of 0.65 percent debentures due 2023, were used to prepay in full the July 2020 Term Loan. The remaining net proceeds from the sale of the common shares were invested by Con Edison in its subsidiaries, principally CECONY and O&R, and for other general corporate purposes; and

•Issued $650 million aggregate principal amount of 0.65 percent debentures, due 2023, with an option to redeem at par, in whole or in part, on or after December 1, 2021. The proceeds from the $650 million refinancing, together with a portion of the proceeds from the sale of common shares, were used to prepay in full the July 2020 Term Loan. See Note C to the financial statements in Item 8.

2019

•Redeemed in advance of maturity $400 million of 2.00 percent 3-year debentures;

•Entered into a forward sale agreement relating to 5,800,000 shares of its common stock. In June 2019, the company issued 4,750,000 shares for $400 million upon physical settlement of shares subject to the forward sale agreement. Con Edison used the proceeds to invest in CECONY for funding of its capital requirements and other general corporate purposes. See Note C to the financial statements in Item 8;

•Issued 5,649,369 common shares for $425 million upon physical settlement of the remaining shares subject to its November 2018 forward sale agreements. Con Edison used the proceeds to invest in its subsidiaries for funding of their capital requirements and to repay short-term debt incurred for that purpose; and

•Borrowed $825 million under a variable-rate term loan that matures in June 2021 to fund the repayment of a six-month variable-rate term loan. In June 2019 and January 2021, Con Edison optionally pre-paid $150 million and $275 million, respectively, of the amount borrowed. See Note C to the financial statements in Item 8.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 81

2018

•Issued 9,324,123 common shares for $705 million pursuant to forward sale agreements and borrowed $825 million under a 6-month variable rate term loan, which amounts, along with $79 million of other company funds, were used to pay the purchase price for the acquisition by the Clean Energy Businesses of Sempra Solar Holdings, LLC. In February 2019, the company repaid the $825 million term loan with borrowings under a variable-rate term loan that matures in June 2021. See Notes C and V to the financial statements in Item 8.

Con Edison’s cash flows from financing activities in 2020, 2019 and 2018 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 $106 million, $101 million and $100 million, respectively.

Net cash flows from financing activities during the years ended December 31, 2020, 2019 and 2018 reflect the following CECONY transactions:

2020

•Issued $600 million aggregate principal amount of 3.00 percent debentures, due 2060, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes;

•Redeemed at maturity $350 million of 4.45 percent 10-year debentures; and

•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 a portion of the net proceeds for repayment of short-term debt and temporarily placed the remaining net proceeds in short-term interest-bearing instruments.

2019

•Issued $600 million aggregate principal amount of 3.70 percent debentures, due 2059, and $700 million aggregate principal amount of 4.125 percent debentures, due 2049, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes; and

•Redeemed at maturity $475 million of 6.65 percent 10-year debentures.

2018

•Issued $500 million aggregate principal amount of 4.00 percent debentures, due 2028, and $600 million aggregate principal amount of 4.65 percent debentures, due 2048, the net proceeds from the sale of which were used to redeem at maturity $600 million of 7.125 percent 10-year debentures and other general corporate purposes, including repayment of short-term debt;

•Issued $640 million aggregate principal amount of debentures, due 2021, at a variable interest rate of 0.40 percent above three-month LIBOR and redeemed $636 million of its tax-exempt debt for which the interest rates were to be determined pursuant to periodic auctions;

•Issued $700 million aggregate principal amount of 4.50 percent debentures, due 2058, and $300 million aggregate principal amount of 3.80 percent debentures, due 2028, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes; and

•Redeemed at maturity $600 million of 5.85 percent 10-year debentures.

Net cash flows from financing activities during the years ended December 31, 2020, 2019 and 2018 also reflect the following O&R transactions:

2020

•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, the net proceeds from the sales of which were used to repay short-term borrowings and for other general corporate purposes.

82 CON EDISON ANNUAL REPORT 2020

2019

•Issued $43 million aggregate principal amount of 3.73 percent debentures, due 2049, $44 million aggregate principal amount of 2.94 percent debentures, due 2029, and $38 million aggregate principal amount of 3.46 percent debentures, due 2039, the net proceeds from the sales of which were used to repay short-term borrowings and for other general corporate purposes; and

•Redeemed at maturity $60 million of 4.96 percent 10-year debentures.

2018

•Redeemed at maturity $50 million of 6.15 percent 10-year debentures; and

•Issued $150 million aggregate principal amount of 4.35 percent debentures, due 2048, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes.

Net cash flows from financing activities during the years ended December 31, 2020, 2019 and 2018 also reflect the following Clean Energy Businesses transactions:

2020

•Borrowed $165 million under a $613 million variable-rate construction loan facility that matures no later than November 2021, secured by three of the company’s solar electric production projects. See Note D to the financial statements in Item 8.

2019

•Issued $303 million aggregate principal amount of 3.82 percent senior notes, due 2038, secured by the company's California Solar 4 renewable electric production projects; and

•Borrowed $464 million at a variable-rate, due 2026, secured by equity interests in solar electric production projects, the net proceeds from the sale of which were used to repay borrowings from Con Edison and for other general corporate purposes. Con Edison used a portion of the repayment to pre-pay $150 million of an $825 million variable-rate term loan that matures in June 2021 (see Note C to the financial statements in Item 8) and the remainder to repay short-term borrowings and for other general corporate purposes. The company has entered into fixed-rate interest rate swaps in connection with this borrowing. See Note P to the financial statements in Item 8.

2018

•Issued $140 million aggregate principal amount of 4.41 percent senior notes, due 2028, secured by the company’s Wind Holdings renewable electric production projects.

Cash flows from financing activities of the Companies also reflect commercial paper issuance. The commercial paper amounts outstanding at December 31, 2020, 2019 and 2018 and the average daily balances for 2020, 2019 and 2018 for Con Edison and CECONY were as follows:

	2020				2019				2018
(Millions of Dollars, except Weighted Average Yield)	Outstanding at December 31		Daily average		Outstanding at December 31		Daily average		Outstanding at December 31		Daily average
Con Edison	$1,705		$980		$1,692		$1,074		$1,741		$889
CECONY	$1,660		$678		$1,137		$734		$1,192		$532
Weighted average yield	0.3	%	1.0	%	2.0	%	2.5	%	3.0	%	2.3	%

Common stock issuances and external borrowings are sources of liquidity that could be affected by changes in credit ratings, financial performance and capital market conditions. For information about the Companies’ credit ratings and certain financial ratios, see “Capital Requirements and Resources” in Item 1.

Capital Requirements and Resources

For information about capital requirements, contractual obligations and capital resources, see “Capital Requirements and Resources” in Item 1.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 83

Assets, Liabilities and Equity

The Companies’ assets, liabilities and equity at December 31, 2020 and 2019 are summarized as follows:

	CECONY		O&R		Clean Energy Businesses		Con Edison Transmission		Other (a)		Con Edison (b)
(Millions of Dollars)	2020	2019	2020	2019	2020	2019	2020	2019	2020	2019	2020	2019
ASSETS
Current assets	$4,407	$3,543	$277	$243	$485	$511	$42	$2	$90	$(27)	$5,301	$4,272
Investments	541	461	26	26	—	—	1,256	1,585	(7)	(7)	1,816	2,065
Net plant	39,554	37,414	2,469	2,336	4,515	4,121	17	17	—	1	46,555	43,889
Other noncurrent assets	6,465	5,139	475	401	1,848	1,896	33	14	402	403	9,223	7,853
Total Assets	$50,967	$46,557	$3,247	$3,006	$6,848	$6,528	$1,348	$1,618	$485	$370	$62,895	$58,079
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	$5,247	$4,131	$356	$311	$1,330	$1,525	$111	$135	$310	$185	$7,354	$6,287
Noncurrent liabilities	14,722	13,665	1,191	1,115	211	201	28	88	(58)	(17)	16,094	15,052
Long-term debt	16,149	14,614	893	818	2,776	2,400	500	500	64	195	20,382	18,527
Equity	14,849	14,147	807	762	2,531	2,402	709	895	169	7	19,065	18,213
Total Liabilities and Equity	$50,967	$46,557	$3,247	$3,006	$6,848	$6,528	$1,348	$1,618	$485	$370	$62,895	$58,079

(a) Includes parent company and consolidation adjustments.

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

CECONY

Current assets at December 31, 2020 were $864 million higher than at December 31, 2019. The change in current assets primarily reflects increases in accounts receivables, less allowance for uncollectible accounts ($442 million) (see “COVID-19 Regulatory Matters” in Note B to the financial statements in Item 8 and “Coronavirus Disease 2019 (COVID-19) Impacts - Accounting Considerations” and “Liquidity and Financing,” above), cash and temporary cash investments ($134 million), regulatory assets ($131 million), revenue decoupling mechanism receivable ($53 million), accrued unbilled revenue ($46 million) and accounts receivables from affiliated companies ($61 million).

Investments at December 31, 2020 were $80 million higher than at December 31, 2019. The change in investments primarily reflects increases in supplemental retirement income plan assets ($68 million) and deferred income plan assets ($11 million). See "Investments" in Note A and Note E to the financial statements in Item 8.

Net plant at December 31, 2020 was $2,140 million higher than at December 31, 2019. The change in net plant primarily reflects an increase in electric ($1,338 million), gas ($692 million), steam ($95 million) and general ($314 million) plant balances and an increase in construction work in progress ($508 million), offset in part by an increase in accumulated depreciation ($807 million).

Other noncurrent assets at December 31, 2020 were $1,326 million higher than at December 31, 2019. The change in other noncurrent assets primarily reflects an increase 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 ($662 million). The change in the regulatory asset also reflects increases in the regulatory assets for deferred pension and other postretirement benefits ($225 million), environmental remediation costs ($144 million), deferrals for increased costs related to the COVID-19 pandemic ($113 million), deferred storm costs ($83 million) and the year's amortization of accounting costs. See Notes B, E, F and G to the financial statements in Item 8.

Current liabilities at December 31, 2020 were $1,116 million higher than at December 31, 2019. The change in current liabilities primarily reflects increases in notes payable ($523 million), debt due within one year as of December 31, 2020 ($290 million) and accounts payable ($276 million).

84 CON EDISON ANNUAL REPORT 2020

Noncurrent liabilities at December 31, 2020 were $1,057 million higher than at December 31, 2019. The change in noncurrent liabilities primarily reflects an increase in the liability for pension and retiree benefits ($702 million) as a result of the final actuarial valuation of the pension and other retiree benefit plans, as measured at December 31, 2020, in accordance with the accounting rules for retirement benefits. The change also reflects an increase in deferred income taxes and unamortized investment tax credits ($411 million), primarily due to accelerated tax depreciation and repair deductions. See Notes E, F, and L to the financial statements in Item 8.

Long-term debt at December 31, 2020 was $1,535 million higher than at December 31, 2019. The change in long-term debt primarily reflects the March and November 2020 issuance of $2,200 million of debentures, offset in part by the reclassification of $640 million of long-term debt to long-term debt due within one year. See "Liquidity and Capital Resources - Cash Flows From Financing Activities" above and Note C to the financial statements in Item 8.

Equity at December 31, 2020 was $702 million higher than at December 31, 2019. The change in equity reflects net income for the year ($1,185 million) and capital contributions from parent ($500 million) in 2020, offset in part by common stock dividends to parent ($982 million) in 2020.

O&R

Current assets at December 31, 2020 were $34 million higher than at December 31, 2019. The change in current assets primarily reflects increases in accounts receivables, less allowance for uncollectible accounts ($16 million), revenue decoupling mechanism receivable ($8 million), regulatory assets ($8 million) and cash and temporary cash investments ($5 million).

Net plant at December 31, 2020 was $133 million higher than at December 31, 2019. The change in net plant primarily reflects an increase in electric ($111 million) and gas ($46 million) plant balances and an increase in construction work in progress ($31 million), offset in part by an increase in accumulated depreciation ($59 million).

Other noncurrent assets at December 31, 2020 were $74 million higher than at December 31, 2019. The change in other noncurrent assets primarily reflects an increase in the regulatory asset for unrecognized pension and other postretirement costs as a result of 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 ($38 million) and an increase in the regulatory asset for deferred storm costs ($35 million). See Notes B, E and F to the financial statements in Item 8. The change in the regulatory asset also reflects the year's amortization of accounting costs.

Current liabilities at December 31, 2020 were $45 million higher than at December 31, 2019. The change in current liabilities primarily reflects higher accounts payable.

Noncurrent liabilities at December 31, 2020 were $76 million higher than at December 31, 2019. The change in noncurrent liabilities primarily reflects an increase in the liability for pension and retiree benefits ($37 million), as a result of the final actuarial valuation of the pension and other retiree benefit plans, as measured at December 31, 2020 in accordance with the accounting rules for retirement benefits and an increase in the regulatory liability for deferred other retiree benefit plans rate ($9 million). It also reflects an increase in deferred income taxes and unamortized investment tax credits ($24 million), primarily due to accelerated tax depreciation and repair deductions. See Notes E, F, and L to the financial statements in Item 8.

Long-term debt at December 31, 2020 was $75 million higher than at December 31, 2019. The change in long-term debt reflects the September 2020 issuance of $75 million of debentures. See "Liquidity and Capital Resources - Cash Flows From Financing Activities" above.

Equity at December 31, 2020 was $45 million higher than at December 31, 2019. The change in equity reflects net income for the year ($71 million) and capital contributions from parent ($25 million) in 2020, offset by common stock dividends to parent ($49 million) in 2020 and a decrease in other comprehensive income ($2 million).

Clean Energy Businesses

Current assets at December 31, 2020 were $26 million lower than at December 31, 2019. The change in current assets primarily reflects a decrease in restricted cash.

Net plant at December 31, 2020 was $394 million higher than at December 31, 2019. The change in net plant primarily reflects additional capital expenditures, offset in part by an increase in accumulated depreciation.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 85

Other noncurrent assets at December 31, 2020 were $48 million lower than at December 31, 2019. The change in other noncurrent assets primarily reflects the amortization of the purchase power agreement intangible assets.

Current liabilities at December 31, 2020 were $195 million lower than at December 31, 2019. The change in current liabilities primarily reflects the reclassification of the company’s PG&E-related non-recourse project debt with a maturity longer than one year from long-term debt due within one year to long-term debt ($898 million), offset in part by the reclassification of an intercompany loan agreement from the parent company from long-term debt to current liabilities ($400 million) and a borrowing under a short-term construction loan facility ($165 million) (see Note D to the financial statements in Item 8) and additional working capital requirements.

Noncurrent liabilities at December 31, 2020 were $10 million higher than at December 31, 2019. The change in noncurrent liabilities primarily reflects the change in the fair value of derivative liabilities and asset retirement obligations for new projects placed in service, offset in part by the change in deferred taxes and the reduction of lease liability associated with the adoption of ASU No. 2016-02 “Leases (Topic 842)."

Long-term debt at December 31, 2020 was $376 million higher than at December 31, 2019. The change in long-term debt primarily reflects the reclassification of the company’s PG&E-related non-recourse project debt with a maturity longer than one year from long-term debt due within one year to long-term debt ($898 million), offset in part by the reclassification of an intercompany loan agreement from the parent company from long-term debt to current liabilities ($400 million).

Equity at December 31, 2020 was $129 million higher than at December 31, 2019. The change in equity primarily reflects capital contributions from parent ($100 million) in 2020, an increase in noncontrolling interest ($27 million) in 2020 and net income for common stock for the year ($24 million), offset in part by common stock dividends to parent ($21 million) in 2020.

Con Edison Transmission

Current assets at December 31, 2020 were $40 million higher than at December 31, 2019. The change in current assets primarily reflects a receivable of $38 million from Crestwood Pipeline and Storage Northeast LLC (Crestwood), the joint venture partner in Stagecoach Gas Services, LLC. The agreement between Crestwood and Con Edison Gas Pipeline and Storage, LLC (CET Gas) provides for payments from Crestwood to CET Gas for shortfalls in meeting certain earnings growth performance targets. The payment is expected to total $57 million ($19 million of which is due in March 2021 and an additional $19 million plus interest due in each of January 2022 and January 2023. The payments were recorded as a receivable by CET Gas as of December 31, 2020). See "Con Edison Transmission - CET Gas" in Item 1.

Investments at December 31, 2020 were $329 million lower than at December 31, 2019. The change in investments primarily reflects the impairment loss related to Con Edison Transmission's investment in Mountain Valley Pipeline, LLC ($320 million), the decrease in CET Gas' investment in Stagecoach Gas Services, LLC due to the receivable from Crestwood described above ($57 million) and investment income less partnership distribution from Stagecoach Services ($22 million), offset in part by investment income from Mountain Valley Pipeline, LLC ($60 million) and from NY Transco ($8 million), respectively. See "Investments" in Note A to the financial statements in Item 8.

Noncurrent assets at December 31, 2020 were $19 million higher than at December 31, 2019. The change in noncurrent assets reflects a receivable of $19 million related to the receivable from Crestwood described above.

Current liabilities at December 31, 2020 were $24 million lower than at December 31, 2019. The change in current liabilities primarily reflects a reduction in short-term borrowings under an intercompany capital funding facility.

Noncurrent liabilities at December 31, 2020 was $60 million lower than at December 31, 2019. The change in noncurrent liabilities primarily reflects a change in deferred income taxes and unamortized investment tax credits that primarily reflects timing differences associated with investments in partnerships.

Equity at December 31, 2020 was $186 million lower than at December 31, 2019. The change in equity reflects net loss for the year ($175 million) and common stock dividends to parent ($11 million) in 2020.

86 CON EDISON ANNUAL REPORT 2020

Off-Balance Sheet Arrangements

At December 31, 2020, none of the Companies’ transactions, agreements or other contractual arrangements meet the SEC definition of off-balance sheet arrangements.

Regulatory Matters

For information about the Utilities’ rate plans and other regulatory matters affecting the Companies, see “Utility Regulation” in Item 1 and Note B to the financial statements in Item 8.

Risk Factors

The Companies’ businesses are influenced by many factors that are difficult to predict, and that involve uncertainties that may materially affect actual operating results, cash flows and financial condition. See “Risk Factors” in Item 1A.

Application of Critical Accounting Policies

The Companies’ financial statements reflect the application of their accounting policies, which conform to accounting principles generally accepted in the United States of America. The Companies’ critical accounting policies include industry-specific accounting applicable to regulated public utilities and accounting for pensions and other postretirement benefits, contingencies, long-lived assets, cloud computing implementation costs, derivative instruments and investments.

Accounting for Regulated Public Utilities

The Utilities are subject to the accounting rules for regulated operations and the accounting requirements of the FERC and the state public utility regulatory commissions having jurisdiction.

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

The Utilities’ principal regulatory assets and liabilities are listed in Note B to the financial statements in Item 8. The Utilities are receiving or being credited with a return on all of their regulatory assets for which a cash outflow has been made. The Utilities are paying or being charged with a return on all of their regulatory liabilities for which a cash inflow has been received. The Utilities' regulatory assets and liabilities at December 31, 2020 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by the applicable public utility regulatory commission.

In the event that regulatory assets of the Utilities were no longer probable of recovery, as required by the accounting rules for regulated operations, these regulatory assets would be charged to earnings. At December 31, 2020, the regulatory assets for Con Edison and CECONY were $6,461 million and $5,989 million, respectively.

Accounting for Pensions and Other Postretirement Benefits

The Utilities provide pensions and other postretirement benefits to substantially all of their employees and retirees. The Clean Energy Businesses and Con Edison Transmission also provide such benefits to transferred employees who previously worked for the Utilities. The Companies account for these benefits in accordance with the accounting rules for retirement benefits. In addition, the Utilities apply the accounting rules for regulated operations to account for the regulatory treatment of these obligations (which, as described in Note B to the financial statements in Item 8, reconciles the amounts reflected in rates for the costs of the benefit to the costs actually incurred). In applying these accounting policies, the Companies have made critical estimates related to actuarial assumptions, including assumptions of expected returns on plan assets, discount rates, health care cost trends and future compensation. See Notes A, E and F to the financial statements in Item 8 for information about the Companies’ pension and other postretirement benefits, the actuarial assumptions, actual performance, amortization of investment and other actuarial gains and losses and calculated plan costs for 2020, 2019 and 2018.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 87

The discount rate for determining the present value of future period benefit payments is determined using a model to match the durations of highly-rated (Aa or higher by either Moody’s or S&P) corporate bonds with the projected stream of benefit payments.

In determining the health care cost trend rate, the Companies review actual recent cost trends and projected future trends.

The cost of pension and other postretirement benefits in future periods will depend on actual returns on plan assets, assumptions for future periods, contributions and benefit experience. Con Edison’s and CECONY’s current estimates for 2021 are increases, compared with 2020, in their pension and other postretirement benefits costs of $15 million and $13 million, respectively.

The following table illustrates the effect on 2021 pension and other postretirement costs of changing the critical actuarial assumptions, while holding all other actuarial assumptions constant:

Actuarial Assumption	Change in Assumption		Pension	Other Postretirement Benefits	Total
			(Millions of Dollars)
Increase in accounting cost:
Discount rate
Con Edison	(0.25)	%	$72	$4	$76
CECONY	(0.25)	%	$69	$3	$72
Expected return on plan assets
Con Edison	(0.25)	%	$38	$2	$40
CECONY	(0.25)	%	$36	$2	$38
Health care trend rate
Con Edison	1.00	%	$—	$16	$16
CECONY	1.00	%	$—	$11	$11
Increase in projected benefit obligation:
Discount rate
Con Edison	(0.25)	%	$801	$45	$846
CECONY	(0.25)	%	$761	$36	$797
Health care trend rate
Con Edison	1.00	%	$—	$108	$108
CECONY	1.00	%	$—	$79	$79

A 5.0 percentage point variation in the actual annual return in 2021, as compared with the expected annual asset return of 7.00 percent, would change pension and other postretirement benefit costs for Con Edison and CECONY by approximately $29 million and $27 million, respectively, in 2022.

Pension benefits are provided through a pension plan maintained by Con Edison to which CECONY, O&R, the Clean Energy Businesses and Con Edison Transmission make contributions for their participating employees. Pension accounting by the Utilities includes an allocation of plan assets.

The Companies’ policy is to fund their pension and other postretirement benefit accounting costs to the extent tax deductible, and for the Utilities, to the extent these costs are recovered under their rate plans. The Companies were not required to make cash contributions to the pension plan in 2020 under funding regulations and tax laws. However, CECONY and O&R made discretionary contributions to the pension plan in 2020 of $435 million and $40 million, respectively. In 2021, CECONY and O&R expect to make contributions to the pension plan of $441 million and $39 million, respectively. See “Expected Contributions” in Notes E and F to the financial statements in Item 8.

Accounting for Contingencies

The accounting rules for contingencies apply to an existing condition, situation or set of circumstances involving uncertainty as to possible loss that will ultimately be resolved when one or more future events occur or fail to occur. Known material contingencies, which are described in the notes to the financial statements, include certain regulatory matters (Note B), the Utilities’ responsibility for hazardous substances, such as asbestos, PCBs and coal

88 CON EDISON ANNUAL REPORT 2020

tar that have been used or generated in the course of operations (Note G) and other contingencies (Note H). In accordance with the accounting rules, the Companies have accrued estimates of losses relating to the contingencies as to which loss is probable and can be reasonably estimated, and no liability has been accrued for contingencies as to which loss is not probable or cannot be reasonably estimated.

The Utilities recover costs for asbestos lawsuits, workers’ compensation and environmental remediation pursuant to their current rate plans. Generally, changes during the terms of the rate plans to the amounts accrued for these contingencies would not impact earnings.

Accounting for Long-Lived and Intangible Assets

The accounting rules for certain long-lived assets and intangible assets with definite lives require testing for recoverability whenever events or changes in circumstances indicate their carrying amounts may not be recoverable. The carrying amount of a long-lived asset or intangible asset with a definite life is deemed not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. Under the accounting rules, an impairment loss is recognized if the carrying amount is not recoverable from such cash flows, and exceeds its fair value, which approximates market value.

In January 2019, Pacific Gas and Electric Company (PG&E) filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code. The output of certain of the Clean Energy Businesses' renewable electric production projects is sold to PG&E under long-term power purchase agreements. As a result of the PG&E bankruptcy, distributions from the related projects to the Clean Energy Businesses were restricted and PG&E-related project debt was reclassified on Con Edison’s consolidated balance sheet from long-term debt to long-term debt due within one year. In July 2020, PG&E’s plan of reorganization became effective and the Clean Energy Businesses began receiving previously restricted distributions and all related project debt with a maturity longer than one year was reclassified to long-term debt. See “Long-Lived and Intangible Assets” in Note A to the financial statements in Item 8.

Accounting for Cloud Computing Implementation Costs

The accounting rules for costs incurred in implementing cloud computing arrangements allow for capitalization of such costs in the same manner as prepaid assets are recorded. Depreciation on the assets is recorded as other operations and maintenance expense. See "Other Deferred Charges and Noncurrent Assets and Prepayments" in Note A to the financial statements in Item 8.

Accounting for Derivative Instruments

The Companies apply the accounting rules for derivatives and hedging to their derivative financial instruments. The Companies use derivative financial instruments to hedge market price fluctuations in related underlying transactions for the physical purchase and sale of electricity and gas. The Utilities are permitted by their respective regulators to reflect in rates all reasonably incurred gains and losses on these instruments. The Clean Energy Businesses have also hedged interest rate risk on certain debt securities. See “Financial and Commodity Market Risks,” below and Note P to the financial statements in Item 8.

Where the Companies are required to make mark-to-market estimates pursuant to the accounting rules, the estimates of gains and losses at a particular period end do not reflect the end results of particular transactions, and will most likely not reflect the actual gain or loss at the conclusion of a transaction. Substantially all of the estimated gains or losses are based on prices supplied by external sources such as the fair value of exchange-traded futures and options and the fair value of positions for which price quotations are available through or derived from brokers or other market sources.

Investments

The accounting rules require Con Edison to periodically evaluate its equity method investments, 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. The evaluation and measurement of impairments involve uncertainties. The estimates that Con Edison makes with respect to its equity method investments are based on assumptions that management believes are reasonable, and variations in these estimates or the underlying assumptions 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 its proportionate share of that impairment loss and would evaluate its investment for an other-than-temporary decline in value.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 89

Con Edison evaluated its equity method investments as of December 31, 2020 and concluded that the fair value of its investment in Mountain Valley Pipeline LLC (MVP) declined below its carrying value and the decline is other-than-temporary. Accordingly, Con Edison recorded a pre-tax impairment loss of $320 million ($223 million after tax) for the year ended December 31, 2020 that reduced the carrying value of its investment in MVP from $662 million to $342 million. See “Investments” in Note A to the financial statements in Item 8.

There is risk that the carrying value of Con Edison’s investments in MVP may be further or fully impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before the Mountain Valley Pipeline can be completed. Assumptions and estimates used to test Con Edison’s investments in MVP for impairment may change if adverse or delayed resolutions to these matters were to occur, which could have a material adverse effect on the fair value of Con Edison’s investment in MVP. Also, Con Edison is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC. As such strategic alternatives are evaluated, Con Edison may be required to determine whether an other-than-temporary decline in value has occurred for its Stagecoach investment.

At December 31, 2020, Con Edison’s consolidated balance sheet included investments of $1,816 million. See “Investments” in Note A to the financial statements in Item 8.

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 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 P to the financial statements in Item 8. Con Edison and CECONY estimate that at December 31, 2020, a 10 percent increase in interest rates applicable to its variable rate debt would result in an increase in annual interest expense of $1 million. 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 P to the financial statements in Item 8.

Con Edison estimates that, as of December 31, 2020, a 10 percent decline in market prices would result in a decline in fair value of $87 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $81 million is for CECONY and $6 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. See “Recoverable Energy Costs” in Note A to the financial statements in Item 8.

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 years ended December 31, 2020 and 2019, respectively, was as follows:

90 CON EDISON ANNUAL REPORT 2020

95% Confidence Level, One-Day Holding Period	2020	2019
	(Millions of Dollars)
Average for the period	$—	$—
High	—	1
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 “Application of Critical Accounting Policies – Accounting for Pensions and Other Postretirement Benefits,” above and “Investments” in Note A and Notes E and F to the financial statements in Item 8.

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 December 31, 2020, the pension plan investments consisted of 51 percent equity securities, 38 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.

Environmental Matters

For information concerning climate change, environmental sustainability, potential liabilities arising from laws and regulations protecting the environment and other environmental matters, see “Environmental Matters” in Item 1 and Note G to the financial statements in Item 8.

Impact of Inflation

The Companies are affected by the decline in the purchasing power of the dollar caused by inflation. Regulation permits the Utilities to recover through depreciation only the historical cost of their plant assets even though in an inflationary economy the cost to replace the assets upon their retirement will substantially exceed historical costs. The impact is, however, partially offset by the repayment of the Companies’ long-term debt in dollars of lesser value than the dollars originally borrowed.

Material Contingencies

For information concerning potential liabilities arising from the Companies’ material contingencies, see “Application of Critical Accounting Policies – Accounting for Contingencies,” above, and Notes B, G and H to the financial statements in Item 8.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 91

Item 7A: Quantitative and Qualitative Disclosures about Market Risk

Con Edison

For information about Con Edison’s primary market risks associated with activities in derivative financial instruments, other financial instruments and derivative commodity instruments, see “Financial and Commodity Market Risks,” in Item 7 (which information is incorporated herein by reference). See also “The Companies Require Access To Capital Markets To Satisfy Funding Requirements,” in Item 1A.

CECONY

For information about CECONY’s primary market risks associated with activities in derivative financial instruments, other financial instruments and derivative commodity instruments, see “Financial and Commodity Market Risks” in Item 7 (which information is incorporated herein by reference). See also “The Companies Require Access To Capital Markets To Satisfy Funding Requirements,” in Item 1A.

92 CON EDISON ANNUAL REPORT 2020

Item 8:    Financial Statements and Supplementary Data

Financial Statements	Page
Supplementary Financial Information
Con Edison
Report of Management on Internal Control Over Financial Reporting	95
Report of Independent Registered Public Accounting Firm	96
Consolidated Income Statement for the years ended December 31, 2020, 2019, and 2018	99
Consolidated Statement of Comprehensive Income for the years ended December 31, 2020, 2019 and 2018	100
Consolidated Statement of Cash Flows for the years ended December 31, 2020, 2019 and 2018	101
Consolidated Balance Sheet at December 31, 2020 and 2019	102
Consolidated Statement of Equity for the years ended December 31, 2020, 2019 and 2018	104
Consolidated Statement of Capitalization at December 31, 2020 and 2019	105
CECONY
Report of Management on Internal Control Over Financial Reporting	108
Report of Independent Registered Public Accounting Firm	109
Consolidated Income Statement for the years ended December 31, 2020, 2019 and 201818	111
Consolidated Statement of Comprehensive Income for the years ended December 31, 2020, 2019 and 2018	112
Consolidated Statement of Cash Flows for the years ended December 31, 2020, 2019 and 2018	113
Consolidated Balance Sheet at December 31, 202020 and 2019	114
Consolidated Statement of Shareholder’s Equity for the years ended December 31, 2020, 2019 and 2018	116
Consolidated Statement of Capitalization at December 31, 2020 and 2019	117
Notes to the Financial Statements	119
Financial Statement Schedules
Con Edison
Schedule I - Condensed Financial Information of Consolidated Edison, Inc. at December 31, 2020 and 2019 and for the years ended December 31, 2020, 2019 and 2018	187
Schedule II - Valuation and Qualifying Accounts for the years ended December 31, 2020, 2019 and 2018	190
CECONY
Schedule II - Valuation and Qualifying Accounts for the years ended December 31, 2020, 2019 and 2018	190

All other schedules are omitted because they are not applicable or the required information is shown in financial statements or notes thereto.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 93

Supplementary Financial Information

Selected Quarterly Financial Data for the years ended December 31, 2020 and 2019 (Unaudited)

	2020
Con Edison	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	(Millions of Dollars, except per share amounts)
Operating revenues	$3,234	$2,719	$3,333	$2,960
Operating income	808	479	860	507
Net income	375	190	493	43
Basic earnings per share	$1.13	$0.57	$1.47	$0.13
Diluted earnings per share	$1.12	$0.57	$1.47	$0.13

.

	2019
Con Edison	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	(Millions of Dollars, except per share amounts)
Operating revenues	$3,514	$2,744	$3,365	$2,951
Operating income	786	458	867	565
Net income	424	152	473	295
Basic earnings per share	$1.31	$0.46	$1.42	$0.89
Diluted earnings per share	$1.31	$0.46	$1.42	$0.88

In the opinion of Con Edison, these quarterly amounts include all adjustments, consisting only of normal recurring accruals, necessary for a fair presentation. The sum of the quarterly financial information may vary from the annual data due to rounding.

	2020
CECONY	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	(Millions of Dollars)
Operating revenues	$2,854	$2,345	$2,872	$2,576
Operating income	742	389	722	457
Net income	406	152	405	222

	2019
CECONY	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	(Millions of Dollars)
Operating revenues	$3,039	$2,331	$2,877	$2,573
Operating income	726	376	723	524
Net income	412	152	414	272

In the opinion of CECONY, these quarterly amounts include all adjustments, consisting only of normal recurring accruals, necessary for a fair presentation. The sum of the quarterly financial information may vary from the annual data due to rounding.

94 CON EDISON ANNUAL REPORT 2020

Report of Management on Internal Control Over Financial Reporting

Management of Consolidated Edison, Inc. and its subsidiaries (the Company) is responsible for establishing and maintaining adequate internal control over financial reporting. Internal control over financial reporting is a process designed to provide reasonable, but not absolute, assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of the effectiveness of controls to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with policies or procedures may deteriorate.

Management of the Company assessed the effectiveness of internal control over financial reporting as of December 31, 2020, using the criteria established by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control — Integrated Framework (2013). Based on that assessment, management has concluded that the Company had effective internal control over financial reporting as of December 31, 2020.

The effectiveness of the Company’s internal control over financial reporting as of December 31, 2020, has been audited by PricewaterhouseCoopers LLP, the Company’s independent registered public accounting firm, as stated in their report which appears on the following page of this Annual Report on Form 10-K.

/s/ Timothy P. Cawley

Timothy P. Cawley

President and Chief Executive Officer

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

February 18, 2021

                                                                                                                         CON EDISON ANNUAL REPORT 2020 95

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders of Consolidated Edison, Inc.:

Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the consolidated financial statements, including the related notes and financial statement schedules, of Consolidated Edison, Inc. and its subsidiaries (the "Company") as listed in the accompanying index (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.

Change in Accounting Principle

As discussed in Note J to the consolidated financial statements, the Company changed the manner in which it accounts for leases in 2019.

Basis for Opinions

The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Report of Management on Internal Control Over Financial Reporting. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company’s internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) ("PCAOB") and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed 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. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made

96 CON EDISON ANNUAL REPORT 2020

only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Critical Audit Matters

The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (i) relate to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

Accounting for the Effects of Regulatory Matters

As described in Notes A and B to the consolidated financial statements, the Company applies the authoritative guidance for regulated operations, which specifies the economic effects that result from the causal relationship of costs and revenues in the rate-regulated environment and how these effects are to be accounted for by a regulated enterprise. As of December 31, 2020, there were $6,461 million of deferred costs included in regulatory assets and $4,549 million of regulatory liabilities awaiting potential refund or future rate reductions. Under regulatory accounting guidance, if it is probable that costs will be recovered in the future, those costs would be recorded as deferred charges or “regulatory assets.” Similarly, if revenues are recorded for costs expected to be incurred in the future, these revenues would be recorded as deferred credits or “regulatory liabilities.” The Company’s regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable state and federal regulators.

The principal considerations for our determination that performing procedures relating to the accounting for the effects of regulatory matters is a critical audit matter are the significant auditor judgment and subjectivity in performing procedures and evaluating audit evidence relating to the computation of regulatory assets and regulatory liabilities.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s assessment of regulatory proceedings, including the implementation of new regulatory orders or changes to existing regulatory balances. These procedures also included, among others, evaluating the reasonableness of management’s assessment of impacts arising from correspondence with regulators and changes in laws and regulations; evaluating management’s judgments related to the recoverability of regulatory assets and the establishment of regulatory liabilities; and recalculating regulatory assets and liabilities based on provisions and formulas outlined in rate orders and other correspondence with regulators.

Partial Impairment of the Equity Method Investment in Mountain Valley Pipeline LLC ("MVP")

As described in Note A to the consolidated financial statements, the balance of the Company’s equity method investment in MVP, a company developing a proposed gas transmission project (“Project”), was $342 million as of December 31, 2020. Management periodically evaluates its equity method investments to determine whether an other-than-temporary decline in carrying value has occurred and an impairment exists. Management determined that the uncertainty related to obtaining the necessary permits in lieu of the Nationwide Permit 12, the resulting Project costs and the likelihood of the Project not reaching eventual completion have increased, constituting a triggering event which required management to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. Management used a discounted cash flow analysis to estimate the fair value of its investment, resulting in a pre-tax impairment loss of $320 million. The analysis discounted probability-weighted future cash flows, including revenues based on long-term firm transportation contracts, that are secured for the first 20 years following completion of the Project. Management determined that the discount rate and the likelihood that the Project is completed are the most significant and sensitive assumptions.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 97

The principal considerations for our determination that performing procedures relating to the partial impairment of the equity method investment in MVP is a critical audit matter are (i) the significant judgment by management when developing the fair value measurement of the investment, (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating audit evidence related to management’s significant assumptions related to the probability of completion of the Project and the discount rate, and (iii) the audit effort involved the use of professionals with specialized skill and knowledge.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s impairment assessment for the equity method investment in MVP, including controls over the discounted cash flow analysis and development of the significant assumptions related to the probability of completion of the Project and the discount rate. These procedures also included, among others, (i) evaluating management’s impairment assessment for MVP, (ii) evaluating the appropriateness of the discounted cash flow analysis, (iii) testing the completeness and accuracy of the underlying data used in the discounted cash flow analysis, and (iv) evaluating the significant assumptions used by management related to the probability of completion of the Project and the discount rate. Evaluating management’s assumption related to the probability of completion of the Project involved evaluating whether the assumption used by management was reasonable considering (i) the status of the permitting process with the relevant authorities and (ii) external market and industry data. Professionals with specialized skill and knowledge were used to assist in the evaluation of the discounted cash flow analysis and the discount rate assumption.

/s/ PricewaterhouseCoopers LLP

New York, New York

February 18, 2021

We have served as the Company’s or its predecessors' auditor since 1938.

98 CON EDISON ANNUAL REPORT 2020

Consolidated Edison, Inc.

Consolidated Income Statement

	For the Years Ended December 31,
(Millions of Dollars/Except Share Data)	2020	2019	2018
OPERATING REVENUES
Electric	$8,730	$8,694	$8,612
Gas	2,269	2,391	2,327
Steam	508	627	631
Non-utility	739	862	767
TOTAL OPERATING REVENUES	12,246	12,574	12,337
OPERATING EXPENSES
Purchased power	1,600	1,546	1,644
Fuel	156	207	263
Gas purchased for resale	527	880	1,041
Other operations and maintenance	2,814	3,175	3,152
Depreciation and amortization	1,920	1,684	1,438
Taxes, other than income taxes	2,575	2,406	2,266
TOTAL OPERATING EXPENSES	9,592	9,898	9,804
Gain on acquisition of Sempra Solar Holdings, LLC	—	—	131
OPERATING INCOME	2,654	2,676	2,664
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	(214)	96	119
Other income	23	45	17
Allowance for equity funds used during construction	17	14	12
Other deductions	(227)	(104)	(210)
TOTAL OTHER INCOME (DEDUCTIONS)	(401)	51	(62)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,253	2,727	2,602
INTEREST EXPENSE
Interest on long-term debt	915	888	780
Other interest	118	116	49
Allowance for borrowed funds used during construction	(14)	(13)	(10)
NET INTEREST EXPENSE	1,019	991	819
INCOME BEFORE INCOME TAX EXPENSE	1,234	1,736	1,783
INCOME TAX EXPENSE	90	296	401
NET INCOME	$1,144	$1,440	$1,382
Income attributable to non-controlling interest	$43	$97	$—
NET INCOME FOR COMMON STOCK	$1,101	$1,343	$1,382
Net income per common share — basic	$3.29	$4.09	$4.43
Net income per common share — diluted	$3.28	$4.08	$4.42
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (IN MILLIONS)	334.8	328.5	311.7
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (IN MILLIONS)	335.7	329.5	312.9

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 99

Consolidated Edison, Inc.

Consolidated Statement of Comprehensive Income

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
NET INCOME	$1,144	$1,440	$1,382
INCOME ATTRIBUTABLE TO NON-CONTROLLING INTEREST	(43)	(97)	—
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	(6)	(5)	10
Other income, net of taxes	—	2	—
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
COMPREHENSIVE INCOME	$1,095	$1,340	$1,392

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

100 CON EDISON ANNUAL REPORT 2020

Consolidated Edison, Inc.

Consolidated Statement of Cash Flows

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
OPERATING ACTIVITIES
Net Income	$1,144	$1,440	$1,382
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,920	1,684	1,438
Impairment of assets	320	—	—
Deferred income taxes	85	308	408
Rate case amortization and accruals	(40)	(116)	(117)
Common equity component of allowance for funds used during construction	(17)	(14)	(12)
Net derivative (gains)/losses	57	27	8
(Gain) on Sale of Assets	—	(14)	—
Unbilled revenue and net unbilled revenue deferrals	(1)	(3)	18
(Gain) on existing project interests due to acquisition of Sempra Solar Holdings, LLC	—	—	(131)
Other non-cash items, net	127	(18)	115
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(543)	23	(140)
Materials and supplies, including fuel oil and gas in storage	(4)	6	(20)
Revenue decoupling mechanism receivable	(61)	(76)	—
Other receivables and other current assets	(134)	54	(62)
Taxes receivable	(6)	29	27
Prepayments	(11)	(73)	(7)
Accounts payable	170	10	(46)
Pensions and retiree benefits obligations, net	285	357	325
Pensions and retiree benefits contributions	(478)	(357)	(479)
Accrued taxes	74	10	(49)
Accrued interest	(4)	24	(35)
Superfund and environmental remediation costs, net	(22)	(9)	(19)
Distributions from equity investments	39	57	107
System benefit charge	(119)	20	92
Deferred charges, noncurrent assets and other regulatory assets	(653)	(492)	(393)
Deferred credits and other regulatory liabilities	10	278	436
Other current and noncurrent liabilities	60	(21)	(151)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,198	3,134	2,695
INVESTING ACTIVITIES
Utility construction expenditures	(3,326)	(3,238)	(3,251)
Cost of removal less salvage	(310)	(295)	(258)
Non-utility construction expenditures	(583)	(248)	(246)
Investments in electric and gas transmission projects	(3)	(205)	(248)
Investments in/acquisitions of renewable electric production projects	(24)	(10)	(19)
Acquisition of Sempra Solar Holdings, LLC, net of cash acquired	—	—	(1,488)
Proceeds from sale of assets	—	192	5
Other investing activities	22	22	34
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,224)	(3,782)	(5,471)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	178	(874)	1,989
Issuance of long-term debt	2,925	3,017	3,030
Retirement of long-term debt	(518)	(1,195)	(1,938)
Debt issuance costs	(47)	(32)	(61)
Common stock dividends	(975)	(924)	(842)
Issuance of common shares - public offering	640	825	705
Issuance of common shares for stock plans	58	54	53
Distribution to noncontrolling interest	(16)	(12)	2
NET CASH FLOWS FROM FINANCING ACTIVITIES	2,245	859	2,938
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	219	211	162
BALANCE AT BEGINNING OF PERIOD	1,217	1,006	844
BALANCE AT END OF PERIOD	$1,436	$1,217	$1,006
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$920	$876	$805
Income taxes	$38	($26)	$—
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$478	$336	$369
Issuance of common shares for dividend reinvestment	$48	$47	$47
Debt assumed with business acquisitions	$—	$—	$568
Software licenses acquired but unpaid as of end of period	$51	$80	$100
Equipment acquired but unpaid as of end of period	$28	33	$—

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 101

Consolidated Edison, Inc.

Consolidated Balance Sheet

 

(Millions of Dollars)	December 31, 2020	December 31, 2019
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$1,272	$981
Accounts receivable — customers, less allowance for uncollectible accounts of $148 and $70 in 2020 and 2019, respectively	1,701	1,236
Other receivables, less allowance for uncollectible accounts of $7 and $4 in 2020 and 2019, respectively	278	184
Taxes receivable	26	20
Accrued unbilled revenue	599	599
Fuel oil, gas in storage, materials and supplies, at average cost	356	352
Prepayments	271	260
Regulatory assets	266	128
Restricted cash	164	236
Revenue decoupling mechanism receivable	137	76
Other current assets	231	200
TOTAL CURRENT ASSETS	5,301	4,272
INVESTMENTS	1,816	2,065
UTILITY PLANT, AT ORIGINAL COST
Electric	33,315	31,866
Gas	10,847	10,107
Steam	2,696	2,601
General	3,880	3,562
TOTAL	50,738	48,136
Less: Accumulated depreciation	11,188	10,322
Net	39,550	37,814
Construction work in progress	2,474	1,937
NET UTILITY PLANT	42,024	39,751
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $522 and $391 in 2020 and 2019, respectively	3,893	3,829
Construction work in progress	638	309
NET PLANT	46,555	43,889
OTHER NONCURRENT ASSETS
Goodwill	446	446
Intangible assets, less accumulated amortization of $228 and $126 in 2020 and 2019, respectively	1,460	1,557
Operating lease right-of-use-asset	837	857
Regulatory assets	6,195	4,859
Other deferred charges and noncurrent assets	285	134
TOTAL OTHER NONCURRENT ASSETS	9,223	7,853
TOTAL ASSETS	$62,895	$58,079

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

102 CON EDISON ANNUAL REPORT 2020

Consolidated Edison, Inc.

Consolidated Balance Sheet

(Millions of Dollars)	December 31, 2020	December 31, 2019
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$1,967	$1,446
Term Loan	165	—
Notes payable	1,705	1,692
Accounts payable	1,475	1,164
Customer deposits	311	346
Accrued taxes	150	76
Accrued interest	149	153
Accrued wages	108	102
Fair value of derivative liabilities	238	123
Regulatory liabilities	36	102
System benefit charge	528	647
Operating lease liabilities	96	65
Other current liabilities	426	371
TOTAL CURRENT LIABILITIES	7,354	6,287
NONCURRENT LIABILITIES
Provision for injuries and damages	178	130
Pensions and retiree benefits	2,257	1,516
Superfund and other environmental costs	857	734
Asset retirement obligations	576	425
Fair value of derivative liabilities	240	105
Deferred income taxes and unamortized investment tax credits	6,475	6,227
Operating lease liabilities	764	809
Regulatory liabilities	4,513	4,827
Other deferred credits and noncurrent liabilities	234	279
TOTAL NONCURRENT LIABILITIES	16,094	15,052
LONG-TERM DEBT	20,382	18,527
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	18,847	18,022
Noncontrolling interest	218	191
TOTAL EQUITY (See Statement of Equity)	19,065	18,213
TOTAL LIABILITIES AND EQUITY	$62,895	$58,079

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 103

Consolidated Edison, Inc.

Consolidated Statement of Equity

(In Millions/Except Share Data)	Common Stock		Additional Paid-In Capital	Retained Earnings	Treasury Stock		Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Noncontrolling Interest
	Shares	Amount			Shares	Amount				Total
BALANCE AS OF DECEMBER 31, 2017	310	$34	$6,298	$10,235	23	$(1,038)	$(85)	$(26)	$7	$15,425
Net income				1,382						$1,382
Common stock dividends ($2.86 per share)				(889)						(889)
Issuance of common shares - public offering	11		719				(14)			705
Issuance of common shares for stock plans			100							100
Other comprehensive income								10		10
Noncontrolling interest									106	106
BALANCE AS OF DECEMBER 31, 2018	321	$34	$7,117	$10,728	23	$(1,038)	$(99)	$(16)	$113	$16,839
Net income				1,343					97	$1,440
Common stock dividends ($2.96 per share)				(971)						(971)
Issuance of common shares - public offering	12	1	835				(11)			825
Issuance of common shares for stock plans			102							102
Other comprehensive income								(3)		(3)
Noncontrolling interest									(19)	(19)
BALANCE AS OF DECEMBER 31, 2019	333	$35	$8,054	$11,100	23	$(1,038)	$(110)	$(19)	$191	$18,213
Net income				1,101					43	$1,144
Common stock dividends ($3.06 per share)				(1,023)						(1,023)
Issuance of common shares - public offering	9	1	641				(2)			640
Issuance of common shares for stock plans			113							113
Other comprehensive income								(6)		(6)
Noncontrolling interest									(16)	(16)
BALANCE AS OF DECEMBER 31, 2020	342	$36	$8,808	$11,178	23	$(1,038)	$(112)	$(25)	$218	$19,065

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

104 CON EDISON ANNUAL REPORT 2020

Consolidated Edison, Inc.

Consolidated Statement of Capitalization

	Shares outstanding December 31,		At December 31,
(In Millions)	2020	2019	2020	2019
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$342	$333	$18,872	$18,041
Pension plan liability adjustments, net of taxes			(23)	(17)
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes			(2)	(2)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES			(25)	(19)
Equity			18,847	18,022
Noncontrolling interest			218	191
TOTAL EQUITY (See Statement of Equity)			$19,065	$18,213

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 105

Consolidated Edison, Inc.

Consolidated Statement of Capitalization

LONG-TERM DEBT (Millions of Dollars)				At December 31,
Maturity	Interest Rate		Series	2020	2019
DEBENTURES:
2020	4.45		2010A	$—	$350
2021	2.00		2016A	500	500
2021	0.65	(a)	2018C	640	640
2023	0.65		2020A	650	—
2024	3.30		2014B	250	250
2026	2.90		2016B	250	250
2027	6.50		1997F	80	80
2027	3.125		2017B	350	350
2028	3.80		2018A	300	300
2028	4.00		2018D	500	500
2029	2.94		2019B	44	44
2030	3.35		2020A	600	—
2030	2.02		2020A	35	—
2033	5.875		2003A	175	175
2033	5.10		2003C	200	200
2034	5.70		2004B	200	200
2035	5.30		2005A	350	350
2035	5.25		2005B	125	125
2036	5.85		2006A	400	400
2036	6.20		2006B	400	400
2036	5.70		2006E	250	250
2037	6.30		2007A	525	525
2038	6.75		2008B	600	600
2039	6.00		2009B	60	60
2039	5.50		2009C	600	600
2039	3.46		2019C	38	38
2040	5.70		2010B	350	350
2040	5.50		2010B	115	115
2042	4.20		2012A	400	400
2043	3.95		2013A	700	700
2044	4.45		2014A	850	850
2045	4.50		2015A	650	650
2045	4.95		2015A	120	120
2045	4.69		2015B	100	100
2046	3.85		2016A	550	550
2046	3.88		2016A	75	75
2047	3.875		2017A	500	500
2048	4.65		2018E	600	600
2048	4.35		2018A	125	125
2048	4.35		2018B	25	25
2049	4.125		2019A	700	700
2049	3.73		2019A	43	43
2050	3.95		2020B	1,000	—
2050	3.24		2020B	40	—
2054	4.625		2014C	750	750
2056	4.30		2016C	500	500
2057	4.00		2017C	350	350
2058	4.50		2018B	700	700
2059	3.70		2019B	600	600
2060	3.00		2020C	600	—
TOTAL DEBENTURES				18,565	15,990

106 CON EDISON ANNUAL REPORT 2020

 Consolidated Edison, Inc.

Consolidated Statement of Capitalization

LONG-TERM DEBT (Millions of Dollars)				At December 31,
Maturity	Interest Rate		Series	2020	2019
TAX-EXEMPT DEBT - Notes issued to New York State Energy Research and Development Authority for Facilities Revenue Bonds:
2036	0.11%	(a)	2010A	225	225
2039	0.11	(a)	2004C	99	99
2039	0.09	(a)	2005A	126	126
TOTAL TAX-EXEMPT DEBT				450	450
PROJECT DEBT:
2023	4.04	(b)	Copper Mountain Solar 2	204	224
2024-2032	3.78 - 4.52	(b)	Coram	141	150
2025	4.10	(b)	Copper Mountain Solar 3	264	289
2026	3.72	(b)	CED Southwest	437	456
2028	4.41		Wind Holdings	109	123
2028	3.41	(b)	Copper Mountain Solar 1	56	67
2031	2.24 - 3.03		Mesquite Solar 1	180	193
2031-2038	5.25 - 4.95		Texas Solar 4	54	56
2036	3.94		California Solar 2	93	98
2036	4.07		California Solar 3	82	86
2037	4.78		California Solar	178	184
2038	3.82		California Solar 4	284	297
2039	4.82		Broken Bow II	67	68
2040	4.53		Texas Solar 5	140	145
2041	4.21		Texas Solar 7	192	199
2042	4.45		Upton County Solar	87	90
Other project debt				10	12
TOTAL PROJECT DEBT				2,578	2,737
Other long-term debt				971	974
Unamortized debt expense				(168)	(141)
Unamortized debt discount				(47)	(37)
TOTAL				22,349	19,973
Less: Long-term debt due within one year				1,967	1,446
TOTAL LONG-TERM DEBT				20,382	18,527
TOTAL CAPITALIZATION				$39,229	$36,549

(a) Rates reset weekly or quarterly; December 31, 2020 rates shown.

(b) December 31, 2020 effective rates shown, reflecting variable interest rates on the debt that are reset quarterly or semi-annually and the effect of applicable interest rate swaps, if any.

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 107

Report of Management on Internal Control Over Financial Reporting

Management of Consolidated Edison Company of New York, Inc. and its subsidiaries (the Company) is responsible for establishing and maintaining adequate internal control over financial reporting. Internal control over financial reporting is a process designed to provide reasonable, but not absolute, assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of the effectiveness of controls to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with policies or procedures may deteriorate.

Management of the Company assessed the effectiveness of internal control over financial reporting as of December 31, 2020, using the criteria established by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control – Integrated Framework (2013). Based on that assessment, management has concluded that the Company had effective internal control over financial reporting as of December 31, 2020.

The effectiveness of the Company’s internal control over financial reporting as of December 31, 2020, has been audited by PricewaterhouseCoopers LLP, the Company’s independent registered public accounting firm, as stated in their report which appears on the following page of this Annual Report on Form 10-K.

/s/ Timothy P. Cawley

Timothy P. Cawley

Chief Executive Officer

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

February 18, 2021

108 CON EDISON ANNUAL REPORT 2020

Report of Independent Registered Public Accounting Firm

To the Board of Trustees and Shareholder of Consolidated Edison Company of New York, Inc.:

Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the consolidated financial statements, including the related notes and financial statement schedule, of Consolidated Edison Company of New York, Inc. and its subsidiaries (the “Company”) as listed in the accompanying index (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.

Change in Accounting Principle

As discussed in Note J to the consolidated financial statements, the Company changed the manner in which it accounts for leases in 2019.

Basis for Opinions

The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Report of Management on Internal Control Over Financial Reporting. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed 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. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made

                                                                                                                         CON EDISON ANNUAL REPORT 2020 109

only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Critical Audit Matters

The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

Accounting for the Effects of Regulatory Matters

As described in Notes A and B to the consolidated financial statements, the Company applies the authoritative guidance for regulated operations, which specifies the economic effects that result from the causal relationship of costs and revenues in the rate-regulated environment and how these effects are to be accounted for by a regulated enterprise. As of December 31, 2020, there were $5,989 million of deferred costs included in regulatory assets and $4,105 million of regulatory liabilities awaiting potential refund or future rate reductions. Under regulatory accounting guidance, if it is probable that costs will be recovered in the future, those costs would be recorded as deferred charges or “regulatory assets.” Similarly, if revenues are recorded for costs expected to be incurred in the future, these revenues would be recorded as deferred credits or “regulatory liabilities.” The Company’s regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable state and federal regulators.

The principal considerations for our determination that performing procedures relating to the accounting for the effects of regulatory matters is a critical audit matter are the significant auditor judgment and subjectivity in performing procedures and evaluating audit evidence relating to the computation of regulatory assets and regulatory liabilities.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s assessment of regulatory proceedings, including the implementation of new regulatory orders or changes to existing regulatory balances. These procedures also included, among others, evaluating the reasonableness of management’s assessment of impacts arising from correspondence with regulators and changes in laws and regulations; evaluating management’s judgments related to the recoverability of regulatory assets and the establishment of regulatory liabilities; and recalculating regulatory assets and liabilities based on provisions and formulas outlined in rate orders and other correspondence with regulators.

/s/ PricewaterhouseCoopers LLP

New York, New York

February 18, 2021

We have served as the Company’s auditor since 1938.

110 CON EDISON ANNUAL REPORT 2020

Consolidated Edison Company of New York, Inc.

Consolidated Income Statement

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
OPERATING REVENUES
Electric	$8,103	$8,062	$7,971
Gas	2,036	2,132	2,078
Steam	508	627	631
TOTAL OPERATING REVENUES	10,647	10,821	10,680
OPERATING EXPENSES
Purchased power	1,432	1,357	1,433
Fuel	156	207	263
Gas purchased for resale	426	606	643
Other operations and maintenance	2,269	2,635	2,555
Depreciation and amortization	1,598	1,373	1,276
Taxes, other than income taxes	2,456	2,295	2,156
TOTAL OPERATING EXPENSES	8,337	8,473	8,326
OPERATING INCOME	2,310	2,348	2,354
OTHER INCOME (DEDUCTIONS)
Investment and other income	19	40	13
Allowance for equity funds used during construction	14	12	11
Other deductions	(204)	(87)	(167)
TOTAL OTHER INCOME (DEDUCTIONS)	(171)	(35)	(143)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,139	2,313	2,211
INTEREST EXPENSE
Interest on long-term debt	718	672	662
Other interest	33	67	36
Allowance for borrowed funds used during construction	(12)	(11)	(9)
NET INTEREST EXPENSE	739	728	689
INCOME BEFORE INCOME TAX EXPENSE	1,400	1,585	1,522
INCOME TAX EXPENSE	215	335	326
NET INCOME	$1,185	$1,250	$1,196

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 111

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Comprehensive Income

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
NET INCOME	$1,185	$1,250	$1,196
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	(1)	(3)	1
Other income, net of taxes	—	2	—
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	1
COMPREHENSIVE INCOME	$1,184	$1,249	$1,197

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

112 CON EDISON ANNUAL REPORT 2020

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Cash Flows

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
OPERATING ACTIVITIES
Net income	$1,185	$1,250	$1,196
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,598	1,373	1,276
Deferred income taxes	168	128	354
Rate case amortization and accruals	(40)	(117)	(133)
Common equity component of allowance for funds used during construction	(14)	(12)	(11)
(Gain)/Loss on Sale of Assets	—	(14)	—
Unbilled revenue and net unbilled revenue deferrals	(47)	(3)	(4)
Other non-cash items, net	66	7	13
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(516)	3	(153)
Materials and supplies, including fuel oil and gas in storage	2	11	(17)
Revenue decoupling mechanism receivable	(53)	(76)	—
Other receivables and other current assets	(49)	54	(96)
Accounts receivables from affiliated companies	(61)	141	(150)
Prepayments	19	(61)	(9)
Accounts payable	145	(7)	(27)
Accounts payable to affiliated companies	9	(4)	7
Pensions and retiree benefits obligations, net	253	330	293
Pensions and retiree benefits contributions	(438)	(325)	(440)
Superfund and environmental remediation costs, net	(30)	(12)	(18)
Accrued taxes	61	11	(47)
Accrued taxes to affiliated companies	1	—	(72)
Accrued interest	13	1	(1)
System benefit charge	(112)	18	86
Deferred charges, noncurrent assets and other regulatory assets	(603)	(486)	(314)
Deferred credits and other regulatory liabilities	92	306	549
Other current and noncurrent liabilities	44	(14)	(78)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,693	2,502	2,204
INVESTING ACTIVITIES
Utility construction expenditures	(3,112)	(3,028)	(3,051)
Cost of removal less salvage	(304)	(288)	(255)
Proceeds from sale of assets	—	192	—
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,416)	(3,124)	(3,306)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	523	(55)	1,042
Issuance of long-term debt	2,200	1,300	2,740
Retirement of long-term debt	(350)	(475)	(1,836)
Debt issuance costs	(34)	(21)	(30)
Capital contribution by parent	500	900	120
Dividend to parent	(982)	(912)	(846)
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,857	737	1,190
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	134	115	88
BALANCE AT BEGINNING OF PERIOD	933	818	730
BALANCE AT END OF PERIOD	$1,067	$933	$818
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid during the period for:
Interest	$693	$676	$662
Income taxes	$102	$73	$195
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$417	$285	$299
Software licenses acquired but unpaid as of end of period	$48	$76	95
Equipment acquired but unpaid as of end of period	$28	33	—

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 113

Consolidated Edison Company of New York, Inc.

Consolidated Balance Sheet

(Millions of Dollars)	December 31, 2020	December 31, 2019
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$1,067	$933
Accounts receivable – customers, less allowance for uncollectible accounts of $138 and $65 in 2020 and 2019, respectively	1,595	1,153
Other receivables, less allowance for uncollectible accounts of $4 and $3 in 2020 and 2019, respectively	134	120
Taxes receivable	8	—
Accrued unbilled revenue	523	477
Accounts receivable from affiliated companies	134	73
Fuel oil, gas in storage, materials and supplies, at average cost	291	293
Prepayments	159	178
Regulatory assets	244	113
Revenue decoupling mechanism receivable	129	76
Other current assets	123	127
TOTAL CURRENT ASSETS	4,407	3,543
INVESTMENTS	541	461
UTILITY PLANT AT ORIGINAL COST
Electric	31,327	29,989
Gas	9,921	9,229
Steam	2,696	2,601
General	3,585	3,271
TOTAL	47,529	45,090
Less: Accumulated depreciation	10,297	9,490
Net	37,232	35,600
Construction work in progress	2,320	1,812
NET UTILITY PLANT	39,552	37,412
NON-UTILITY PROPERTY
Non-utility property, less accumulated depreciation of $25 in 2020 and 2019	2	2
NET PLANT	39,554	37,414
OTHER NONCURRENT ASSETS
Regulatory assets	5,745	4,487
Operating lease right-of-use asset	578	601
Other deferred charges and noncurrent assets	142	51
TOTAL OTHER NONCURRENT ASSETS	6,465	5,139
TOTAL ASSETS	$50,967	$46,557

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

114 CON EDISON ANNUAL REPORT 2020

Consolidated Edison Company of New York, Inc.

Consolidated Balance Sheet

(Millions of Dollars)	December 31, 2020	December 31, 2019
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$640	$350
Notes payable	1,660	1,137
Accounts payable	1,232	956
Accounts payable to affiliated companies	22	13
Customer deposits	296	334
Accrued taxes	132	71
Accrued taxes to affiliated companies	1	—
Accrued interest	126	113
Accrued wages	97	92
Fair value of derivative liabilities	163	81
Regulatory liabilities	11	63
System benefit charge	475	587
Operating lease liabilities	73	54
Other current liabilities	319	280
TOTAL CURRENT LIABILITIES	5,247	4,131
NONCURRENT LIABILITIES
Provision for injuries and damages	172	125
Pensions and retiree benefits	1,943	1,241
Superfund and other environmental costs	780	654
Asset retirement obligations	508	362
Fair value of derivative liabilities	105	65
Deferred income taxes and unamortized investment tax credits	6,411	6,000
Operating lease liabilities	512	551
Regulatory liabilities	4,094	4,427
Other deferred credits and noncurrent liabilities	197	240
TOTAL NONCURRENT LIABILITIES	14,722	13,665
LONG-TERM DEBT	16,149	14,614
COMMITMENTS AND CONTINGENCIES (Note B and Note G)
COMMON SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	14,849	14,147
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$50,967	$46,557

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 115

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Shareholder’s Equity

(In Millions)	Common Stock		Additional Paid-In Capital	Retained Earnings	Repurchased Con Edison Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Total
	Shares	Amount
BALANCE AS OF DECEMBER 31, 2017	235	$589	$4,649	$8,231	$(962)	$(62)	$(6)	$12,439
Net income				1,196				1,196
Common stock dividend to parent				(846)				(846)
Capital contribution by parent			120					120
Other comprehensive income							1	1
BALANCE AS OF DECEMBER 31, 2018	235	$589	$4,769	$8,581	$(962)	$(62)	$(5)	$12,910
Net income				1,250				1,250
Common stock dividend to parent				(912)				(912)
Capital contribution by parent			900					900
Other comprehensive income							(1)	(1)
BALANCE AS OF DECEMBER 31, 2019	235	$589	$5,669	$8,919	$(962)	$(62)	$(6)	$14,147
Net income				1,185				1,185
Common stock dividend to parent				(982)				(982)
Capital contribution by parent			500					500
Other comprehensive income							(1)	(1)
BALANCE AS OF DECEMBER 31, 2020	235	$589	$6,169	$9,122	$(962)	$(62)	$(7)	$14,849

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

116 CON EDISON ANNUAL REPORT 2020

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Capitalization

	Shares outstanding
	December 31,		At December 31,
(In Millions)	2020	2019	2020	2019
TOTAL SHAREHOLDER’S EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	235	235	$14,856	$14,153
Pension plan liability adjustments, net of taxes			(5)	—
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes			(2)	(6)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES			(7)	(6)
TOTAL SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)			$14,849	$14,147

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 117

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Capitalization

LONG-TERM DEBT (Millions of Dollars)				At December 31,
Maturity	Interest Rate		Series	2020	2019
DEBENTURES:
2020	4.45		2010A	$—	$350
2021	0.65	(a)	2018C	640	640
2024	3.30		2014B	250	250
2026	2.90		2016B	250	250
2027	3.125		2017B	350	350
2028	3.80		2018A	300	300
2028	4.00		2018D	500	500
2030	3.35		2020A	600	—
2033	5.875		2003A	175	175
2033	5.10		2003C	200	200
2034	5.70		2004B	200	200
2035	5.30		2005A	350	350
2035	5.25		2005B	125	125
2036	5.85		2006A	400	400
2036	6.20		2006B	400	400
2036	5.70		2006E	250	250
2037	6.30		2007A	525	525
2038	6.75		2008B	600	600
2039	5.50		2009C	600	600
2040	5.70		2010B	350	350
2042	4.20		2012A	400	400
2043	3.95		2013A	700	700
2044	4.45		2014A	850	850
2045	4.50		2015A	650	650
2046	3.85		2016A	550	550
2047	3.875		2017A	500	500
2048	4.65		2018E	600	600
2049	4.125		2019A	700	700
2050	3.95		2020B	1,000	—
2054	4.625		2014C	750	750
2056	4.30		2016C	500	500
2057	4.00		2017C	350	350
2058	4.50		2018B	700	700
2059	3.70		2019B	600	600
2060	3.00		2020C	600	—
TOTAL DEBENTURES				16,515	14,665
TAX-EXEMPT DEBT – Notes issued to New York State Energy Research and Development Authority for Facilities Revenue Bonds:
2036	0.11	(a)	2010A	225	225
2039	0.11	(a)	2004C	99	99
2039	0.09	(a)	2005A	126	126
TOTAL TAX-EXEMPT DEBT				450	450
Unamortized debt expense				(130)	(115)
Unamortized debt discount				(46)	(36)
TOTAL				16,789	14,964
Less: Long-term debt due within one year				640	350
TOTAL LONG-TERM DEBT				$16,149	14,614
TOTAL CAPITALIZATION				$30,998	$28,761

(a) Rates reset weekly or quarterly; December 31, 2020 rates shown.

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

118 CON EDISON ANNUAL REPORT 2020

Notes to the Financial Statements

General

These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Orange and Rockland Utilities, Inc. (O&R), Con Edison Clean Energy Businesses, Inc. (together with its subsidiaries, the Clean Energy Businesses) and Con Edison Transmission, Inc. (together with its subsidiaries, Con Edison Transmission) in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R.

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

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., which through its subsidiaries develops, owns and operates renewable and sustainable energy infrastructure projects and provide energy-related products and services to wholesale and retail customers. In December 2018, the Clean Energy Businesses acquired Sempra Solar Holdings, LLC. Con Edison Transmission, Inc. invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and holds investments in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See Note V.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 119

Note A – Summary of Significant Accounting Policies and Other Matters

Principles of Consolidation

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

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.

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

The Utilities’ principal regulatory assets and liabilities are detailed in Note B. In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities at December 31, 2020 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by state regulators.

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

Financial Instruments – Credit Losses

Adoption of New Standard

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.” The amendments replace the incurred loss impairment methodology which involved delayed recognition of credit losses. The amendments introduce an expected credit loss impairment model which requires immediate recognition of anticipated losses over the instrument’s life. A broader range of reasonable and supportable information must be considered in developing the credit loss estimates. The Companies' financial instruments subject to the amendments are included in the lines “Accounts receivable – customers” and “Other receivables.” Substantially all of these in-scope financial instruments are expected to be collected within one year of billing.

The Companies adopted the amendments using the modified retrospective method for all financial instruments measured at amortized costs. Results for reporting periods beginning after January 1, 2020 are presented under Accounting Standards Codification (ASC) 326 while prior period amounts continue to be reported in accordance with previously applicable GAAP. No prior period adjustment or charge to retained earnings for cumulative impact was required as a result of the Companies’ adoption of the amendments.

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.

120 CON EDISON ANNUAL REPORT 2020

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 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, 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.

During the year of 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 customer uncollectible accounts for Con Edison and CECONY were $78 million and $73 million, respectively, for the year ended December 31, 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 year ended December 31, 2020:

	For the Year Ended December 31, 2020
	Con Edison		CECONY
(Millions of Dollars)	Accounts receivable - customers	Other receivables	Accounts receivable - customers	Other receivables
Allowance for credit losses
Beginning Balance at January 1, 2020	$70	$4	$65	$3
Recoveries	8	—	6	—
Write-offs	(54)	(2)	(50)	(1)
Reserve adjustments	124	5	117	2
Ending Balance December 31, 2020	$148	$7	$138	$4

Revenues

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

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

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	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$335	$323	$330
CECONY	323	312	318

For information about the Companies' revenue recognition policies, see Note M.

Plant and Depreciation

Utility Plant

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

Rates used for AFUDC include the cost of borrowed funds and a reasonable rate of return on the Utilities’ own funds when so used, determined in accordance with regulations of the FERC or the state public utility regulatory authority having jurisdiction. The rate is compounded semiannually, and the amounts applicable to borrowed funds are treated as a reduction of interest charges, while the amounts applicable to the Utilities’ own funds are credited to other income (deductions). The AFUDC rates for CECONY were 5.2 percent, 5.1 percent and 5.4 percent for 2020, 2019 and 2018, respectively. The AFUDC rates for O&R were 5.3 percent, 5.3 percent and 2.2 percent for 2020, 2019 and 2018, respectively.

The Utilities generally compute annual charges for depreciation using the straight-line method for financial statement purposes, with rates based on average service lives and net salvage factors. The average depreciation rates for CECONY were 3.5 percent for 2020 and 3.2 percent for 2019 and 2018. The average depreciation rates for O&R were 3.2 percent for 2020, 3.0 percent for 2019 and 2.9 percent for 2018.

The estimated lives for utility plant for CECONY range from 5 to 85 years for electric, 5 to 90 years for gas, 5 to 80 years for steam and 5 to 55 years for general plant. For O&R, the estimated lives for utility plant range from 5 to 75 years for electric and gas and 5 to 50 years for general plant.

At December 31, 2020 and 2019, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Electric
Generation	$572	$591	$572	$591
Transmission	3,786	3,634	3,496	3,380
Distribution	21,481	20,676	20,366	19,602
General	52	43	52	43
Gas (a)	9,206	8,617	8,522	7,961
Steam	1,854	1,813	1,854	1,813
General	2,507	2,365	2,286	2,143
Held for future use	92	75	84	67
Construction work in progress	2,474	1,937	2,320	1,812
Net Utility Plant	$42,024	$39,751	$39,552	$37,412

(a) Primarily distribution.

General utility plant of Con Edison and CECONY included $86 million and $81 million, respectively, at December 31, 2020, and $93 million and $88 million, respectively, at December 31, 2019, related to a May 2018 acquisition of software licenses. The estimated aggregate annual amortization expense for Con Edison and CECONY is $7 million. The accumulated amortization for Con Edison and CECONY was $17 million at December 31, 2020 and $10 million at December 31, 2019.

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Under the Utilities’ rate plans, the aggregate annual depreciation allowance for the period ended December 31, 2020 was $1,694 million, including $1,604 million under CECONY’s electric, gas and steam rate plans that have been approved by the NYSPSC.

Non–Utility Plant

Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the Clean Energy Businesses’ renewable electric production projects. Property, plant and equipment are stated at cost, less accumulated depreciation and include capitalized interest during construction. Depreciation is computed under the straight-line method over the useful lives of the assets. Solar power generating assets and wind power generating assets have useful lives of 35 years and 30, respectively. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives, which is 10 years.

Other Deferred Charges and Noncurrent Assets and Prepayments

Other deferred charges and noncurrent assets and prepayments of Con Edison, net of accumulated depreciation, included $54 million ($51 million for CECONY) and $12 million ($11 million for CECONY), respectively at December 31, 2020, related to implementation costs incurred in cloud computing arrangements. The amounts recorded in 2019 were not material. Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. Depreciation expense related to these assets incurred during the year ended December 31, 2020 for Con Edison and CECONY was $7 million and $6 million, respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $10 million and $8 million, respectively at December 31, 2020 and was not material at December 31, 2019.

Long–Lived and Intangible Assets

The Companies 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 carrying amount of a long-lived asset or intangible asset with a definite life is deemed not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the assets. In the event a test indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are considered impaired and written down to their estimated fair value.

Con Edison's intangible assets with definite lives consist primarily of power purchase agreements, which were identified as part of purchase price allocations associated with acquisitions made by the Clean Energy Businesses in 2016 and 2018. At December 31, 2020 and 2019, intangible assets arising from power purchase agreements, including the PG&E PPAs (discussed below), were $1,457 million and $1,554 million, net of accumulated amortization of $220 million and $119 million, respectively, and are being amortized over the life of each agreement. Excluding power purchase agreements, Con Edison’s other intangible assets were $3 million, net of accumulated amortization of $8 million and $7 million, at December 31, 2020 and 2019, respectively. CECONY’s other intangible assets were immaterial at December 31, 2020 and 2019. Con Edison recorded amortization expense related to its intangible assets of $102 million in 2020, $99 million in 2019, and $14 million in 2018. Con Edison expects amortization expense to be $102 million per year over the next five years. Con Edison recorded $2 million of impairment charges in 2018. No impairment charges were recorded on Con Edison's long-lived assets or intangible assets with definite lives in 2020 or 2019.

In January 2019, Pacific Gas and Electric Company (PG&E) filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code. The output of certain of the Clean Energy Businesses' renewable electric production projects is sold to PG&E under long-term power purchase agreements. As a result of the PG&E bankruptcy, distributions from the related projects to the Clean Energy Businesses were restricted and PG&E-related project debt was reclassified on Con Edison’s consolidated balance sheet from long-term debt to long-term debt due within one year. In July 2020, PG&E’s plan of reorganization became effective and the Clean Energy Businesses began receiving previously restricted distributions and all related project debt with a maturity longer than one year was reclassified to long-term debt.

Recoverable Energy Costs

The Utilities generally recover all of their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state public utility regulators. If the actual energy supply costs for a given month are more or less than the amounts billed to customers for that month,

                                                                                                                         CON EDISON ANNUAL REPORT 2020 123

the difference in most cases is recoverable from or refundable to customers. Differences between actual and billed electric and steam supply costs and costs of its electric demand management programs are generally deferred for charge or refund to customers during the next billing cycle (normally within one or two months). For the Utilities’ gas costs, differences between actual and billed gas costs during the 12-month period ending each August are charged or refunded to customers during a subsequent 12-month period.

New York Independent System Operator (NYISO)

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

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

Temporary Cash Investments

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

Investments

Accounting for 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.

The accounting rules require Con Edison to periodically evaluate its investments 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 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 involves 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 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.

Con Edison evaluated its equity method investments and determined that there was an other-than-temporary decline in the value of its investment in Mountain Valley Pipeline LLC (MVP) and therefore recorded a partial impairment at December 31, 2020, as described below. Also, Con Edison is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC (Stagecoach), a joint venture that owns and operates an existing gas pipeline and storage business located in northeastern Pennsylvania and the southern tier of New York. As such strategic alternatives are evaluated, Con Edison may be required to determine whether an other-than-temporary decline in value has occurred for its Stagecoach investment.

Partial Impairment of Investment in Mountain Valley Pipeline LLC (MVP)

In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET Gas), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed gas transmission project (the Project) in West Virginia and Virginia. At December 31, 2020 and 2019, CET Gas' cash contributions to MVP were approximately $530 million, and the carrying value at December 31, 2020 prior to recording an impairment loss was

124 CON EDISON ANNUAL REPORT 2020

$662 million, reflecting CET Gas' proportionate share of allowance for funds used during construction (AFUDC) income from the Project. During 2019, Con Edison determined that, as it was permitted to do under the MVP joint venture agreement, it would limit its cash contributions to the joint venture to approximately $530 million, which limit was reached in 2019, and that is expected to result in the further reduction of Con Edison’s ownership share in the joint venture. At December 31, 2020, CET Gas owned an 11.3 percent interest in MVP that is expected to be reduced to 8.8 percent based on the current project cost estimate and CET Gas’ previous capping of its cash contributions to the joint venture.

During 2020, progress was made on the construction of the Project, and the U.S. Supreme Court issued favorable decisions in cases unrelated to MVP, regarding the permitting process for pipeline construction and water crossings. In November 2020, the U.S. Court of Appeals for the Fourth Circuit issued a stay on the Nationwide Permit 12, effectively blocking the Project’s ability to pursue water crossings under that permit. As a result, in November 2020 the Project applied to the FERC for a certificate amendment to bore under water bodies in the first 77 miles of the Project in West Virginia, allowing this portion of the pipe to be completed and placed in-service while a plan for the remaining water crossings was pursued. If approved, this amendment would lead to additional Project costs and would extend the anticipated in-service date of the Project to late 2021. The uncertainty related to obtaining the necessary permits in lieu of the Nationwide Permit 12, the resulting Project costs and the likelihood of the Project not reaching eventual completion have increased, constituting a triggering event which required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. Further, in January 2021, the FERC did not approve the requested amendment. In its discussion, a FERC commissioner indicated that the commission should have the plan for the entire Project’s water crossings rather than the first 77 miles and that all of the Federal permits be restored before allowing additional construction to resume. Later in January 2021, the Project indicated its plans to apply for U.S. Army Corps of Engineers individual permits for certain water crossings and a certificate amendment for other water crossings that, in total, would cover the entire Project length. In addition, the second largest partner in the Project announced it had recorded a significant impairment of their investment in the Project at year-end 2020.

In response to the triggering event, Con Edison assessed the value of its equity investment in the Project to determine whether the fair value of its investment in MVP had declined below its carrying value on an other-than-temporary basis. The estimated fair value of the investment was determined using a discounted cash flow analysis, which is a level 3 fair value measurement. The analysis discounted probability-weighted future cash flows, including revenues based on long-term firm transportation contracts, that are secured for the first 20 years following completion of the Project. See Note T. Con Edison has also assumed cash flows extending beyond this period. All cash flows were discounted at a pre-tax discount rate of 8.3 percent and then weighted based on Con Edison’s estimate of the likelihood that the Project will be completed. Con Edison believes that the likelihood of Project completion is in the upper end of a reasonably possible range. The likelihood that the Project is completed and the discount rate are the most significant and sensitive assumptions; changes in these assumptions may materially change the results of the impairment calculation.

Based on the discounted cash flow analysis, Con Edison concluded that the fair value of its investment in MVP declined below its carrying value and the decline is other-than-temporary. Accordingly, Con Edison recorded a pre-tax impairment loss of $320 million ($223 million, after tax), for the year ended December 31, 2020 to reduce the carrying value of its investment in MVP from $662 million to $342 million. The impairment was recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison will not record non-cash equity in earnings from allowance for funds used during construction, if any, from MVP beginning in 2021 and until such time as substantial construction activities are resumed, which would be indicative of probable Project completion.

There is risk that the fair value of Con Edison’s investment in MVP may be further or fully impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before the Project can be completed. Assumptions and estimates used to test Con Edison’s investment in MVP for impairment may change if adverse or delayed resolutions to the Project’s pending legal and regulatory challenges were to occur, which could have a material adverse effect on the fair value of Con Edison’s investment in MVP.

Summary of Investment Balances

The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2020 and 2019:

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	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
CET Gas investment in Stagecoach Gas Services, LLC	$845	$924	$—	$—
CET Gas investment in Mountain Valley Pipeline, LLC (a)	342	602	—	—
Supplemental retirement income plan assets (b)	465	397	439	371
Deferred income plan assets	92	81	92	81
CET Electric investment in New York Transco, LLC	69	59	—	—
Other	3	2	10	9
Total investments	$1,816	$2,065	$541	$461

(a)At December 31, 2020 and 2019, CET Gas' cash investment in MVP was $530 million. In January 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is continuing to target an in-service date for the Project of late 2021 at an overall Project cost of $5,800 million to $6,000 million, excluding allowance for funds used during construction. For the year ended December 31, 2020, CET Gas owned an 11.3 percent interest in MVP and reduced the carrying value of its investment in MVP from $662 million to $342 million by recognizing a noncash impairment loss of $320 million, pre-tax ($223 million, after tax), and based on total estimated Project costs and CET Gas’ previous capping of its cash contributions to the joint venture, its ownership interest in the joint venture is expected to be reduced to 8.8%.

(b)See Note E.

Pension and Other Postretirement Benefits

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

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

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

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

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

126 CON EDISON ANNUAL REPORT 2020

Federal Income Tax

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

Upon enactment of the Tax Cuts and Jobs Act of 2017 on December 22, 2017 (the TCJA), the Companies re-measured their deferred tax assets and liabilities based upon the 21 percent corporate income tax rate under the TCJA. The tax effects of changes in tax laws are to be recognized in the period in which the law is enacted and deferred tax assets and liabilities are to be re-measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. For the Utilities, in accordance with their New York rate plans and the accounting rules for regulated operations, the change in deferred taxes was recorded as either an offset to a regulatory asset or a regulatory liability. For Con Edison’s other businesses, the change in deferred taxes was reflected as a decrease in income tax expense, which increased Con Edison's net income. See “Other Regulatory Matters” and “Regulatory Assets and Liabilities” in Note B and Note L.

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

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

State Income Tax

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

Research and Development Costs

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

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$24	$24	$24
CECONY	23	23	23

Reclassification

Certain prior year amounts have been reclassified within Note L to conform with current year 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 are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 127

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 (see Note N) and its common shares that are subject to forward sale agreements (see Note C). Before the issuance of common shares upon settlement of the forward sale agreements, the shares will be reflected in the company’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of common shares used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreements over the number of shares that could be purchased by the company in the market (based on the average market price during the period) using the proceeds due upon physical settlement (based on the adjusted forward sale price at the end of the reporting period).

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

	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2020	2019	2018
Net income for common stock	$1,101	$1,343	$1,382
Weighted average common shares outstanding – basic	334.8	328.5	311.7
Add: Incremental shares attributable to effect of potentially dilutive securities	0.9	1.0	1.2
Adjusted weighted average common shares outstanding – diluted	335.7	329.5	312.9
Net Income per common share – basic	$3.29	$4.09	$4.43
Net Income per common share – diluted	$3.28	$4.08	$4.42

The computation of diluted EPS for the years ended December 31, 2020, 2019 and 2018 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect.

Estimates

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

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

Changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:

(Millions of Dollars)	Con Edison	CECONY
Accumulated OCI, net of taxes, at December 31, 2017 (a)	$(26)	$(6)
OCI before reclassifications, net of tax of $3 for Con Edison	4	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	6	1
Total OCI, net of taxes, at December 31, 2018	10	1
Accumulated OCI, net of taxes, at December 31, 2018 (a)	$(16)	$(5)
OCI before reclassifications, net of tax of $(6) and $(1) for Con Edison and CECONY, respectively	(10)	(3)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	7	2
Total OCI, net of taxes, at December 31, 2019	(3)	(1)
Accumulated OCI, net of taxes, at December 31, 2019 (a)	$(19)	$(6)
OCI before reclassifications, net of tax of $4 and $1 for Con Edison and CECONY, respectively	(11)	(3)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	5	2
Total OCI, net of taxes, at December 31, 2020	(6)	(1)
Accumulated OCI, net of taxes, at December 31, 2020 (a)	$(25)	$(7)

(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 cost. See Notes E and F.

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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 December 31, 2020 and 2019, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows:

	At December 31,
	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Cash and temporary cash investments	$1,272	$981	$1,067	$933
Restricted cash (a)	164	236	—	—
Total cash, temporary cash investments and restricted cash	$1,436	$1,217	$1,067	$933

(a)Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($164 million and $236 million at December 31, 2020 and 2019, respectively) that, under the related project debt agreements, is either restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves or, for the December 31, 2019 amount, was restricted as a result of the PG&E bankruptcy. During the pendency of the PG&E bankruptcy, cash was not distributed from the related projects to the Clean Energy Businesses. In July 2020, PG&E's plan of reorganization became effective and the Clean Energy Businesses received previously restricted distributions and have resumed receiving distributions for all projects. See "Long-Lived and Intangible Assets,” above.

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Note B – Regulatory Matters

Rate Plans

The Utilities provide service to New York customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary, are approved by the NJBPU. The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator.

Common provisions of the Utilities’ New York rate plans include:

Recoverable energy costs that allow the Utilities to recover on a current basis the costs for the energy they supply with no mark-up to their full-service customers.

Cost reconciliations that reconcile pension and other postretirement benefit costs, environmental remediation costs, property taxes, variable-rate tax-exempt debt and certain other costs to amounts reflected in delivery rates for such costs. In addition, changes in the Utilities' costs not reflected in rates, in excess of certain amounts, resulting from changes in tax or changes in legislation, regulation or related actions, are deferred as a regulatory asset or regulatory liability to be reflected in the Utilities' next rate plan or in a manner to be determined by the NYSPSC. Also, the Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases and provision is sometimes made for the utility to retain a share of cost reductions, for example, property tax refunds.

Revenue decoupling mechanisms that reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC. The difference is accrued with interest for refund to, or recovery from customers, as applicable.

Earnings sharing that require the Utilities to defer for customer benefit a portion of earnings over specified rates of return on common equity. There is no symmetric mechanism for earnings below specified rates of return on common equity.

Negative revenue adjustments for failure to meet certain performance standards relating to service, reliability, safety and other matters.

Positive revenue adjustments for achievement of performance standards related to achievement of clean energy goals, safety and other matters.

Net utility plant reconciliations that require deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates. There is generally no symmetric mechanism if actual average net utility plant balances are more than amounts reflected in rates.

Rate base, as reflected in the rate plans, is, in general, the sum of the Utilities’ net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. For each rate plan, the NYSPSC uses a forecast of the average rate base for each year that new rates would be in effect (“rate year”). 

Weighted average cost of capital is determined based on the authorized common equity ratio, return on common equity, cost of long-term debt and cost of customer deposits reflected in each rate plan. For each rate plan, the revenues designed to provide the utility a return on invested capital for each rate year are determined by multiplying each utility rate base by its pre–tax weighted average cost of capital. The Utilities’ actual return on common equity will reflect their actual operations for each rate year, and may be more or less than the authorized return on equity reflected in their rate plans (and if more, may be subject to earnings sharing).

130 CON EDISON ANNUAL REPORT 2020

The following tables contain a summary of the Utilities’ rate plans:

CECONY – Electric
Effective period	January 2017 – December 2019	January 2020 – December 2022 (a)
Base rate changes	Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b)	Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million	Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d)
Other revenue sources	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively.	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020, the company recorded $34 million primarily related to earnings adjustment mechanism incentives for energy efficiency.
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, the company deferred for recovery from customers $242 million of revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel 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 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million.	Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively.	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2020, the company deferred $288 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively.	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020.
Average rate base	Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million	Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent	6.61 percent
Authorized return on common equity	9.0 percent	8.80 percent

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Actual return on common equity (i)	Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent	Yr. 1 – 8.50 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold.	Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, the company had no earnings sharing above the threshold.
Cost of long-term debt	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent	4.63 percent
Common equity ratio	48 percent	48 percent

(a)In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note T) are not necessary.

(b)The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs.

(c)Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d)Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually).

(e)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.

(f)In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of

30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan.

(g)In addition, the NYSPSC staff has commenced a focused operations audit to investigate the income tax accounting of CECONY and other New York utilities. Any NYSPSC-ordered adjustment to CECONY’s income tax accounting will be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below.

(h)Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas.

(i)Calculated in accordance with the earnings calculation method prescribed in the rate order.

132 CON EDISON ANNUAL REPORT 2020

CECONY – Gas
Effective period	January 2017 - December 2019	January 2020 – December 2022 (a)
Base rate changes	Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million	Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million	Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d)
Other revenue sources	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations.	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020, the company recorded $3 million of earnings adjustment mechanism incentives for energy efficiency. In 2020, the company recorded positive incentives of $13 million.
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, the company deferred for recovery from customers $27 million of revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas 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 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any negative revenue adjustments.	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $81 million Yr. 2 - $88 million Yr. 3 - $96 million In 2020, the company did not record any negative revenue adjustments.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively.	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2020, the company deferred $91 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability.	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $8,108 million Yr. 2 - $8,808 million Yr. 3 - $9,510 million AMI: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020, the company deferred $24.7 million as a regulatory liability.
Average rate base	Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million	Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent	6.61 percent
Authorized return on common equity	9.0 percent	8.80 percent
Actual return on common equity (i)	Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent	Yr. 1 – 8.40 percent

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Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold.	Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent	4.63 percent
Common equity ratio	48 percent	48 percent

(a)In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note T) are not necessary.

(b)The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(c)The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d)Amounts reflect amortization of the remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually)

(e)-(i)    See footnotes (e) - (i) to the table under “CECONY Electric,” above.

134 CON EDISON ANNUAL REPORT 2020

CECONY – Steam
Effective period	January 2014 – December 2016 (a)
Base rate changes	Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None
Amortizations to income of net regulatory (assets) and liabilities	$37 million over three years
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2020, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015, 2016, 2017, 2018, 2019 and 2020, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities and $35 million of net regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020.
Average rate base	Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent
Authorized return on common equity	9.3 percent
Actual return on common equity (d)	Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent
Earnings sharing	Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent
Common equity ratio	48 percent

(a)Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC.

(b)The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016.

(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 10 basis point impact on return on common equity.

(d)Calculated in accordance with the earnings calculation method prescribed in the rate order.

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O&R New York – Electric
Effective period	November 2015 - October 2017 (a)	January 2019 – December 2021 (d)
Base rate changes	Yr. 1 – $9.3 million Yr. 2 – $8.8 million Yr. 3 – None	Yr. 1 – $13.4 million (e) Yr. 2 – $8.0 million (e) Yr. 3 – $5.8 million (e)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $(8.5) million (b) Yr. 2 – $(9.4) million (b) Yr. 3 – None	Yr. 1 – $(1.5) million (f) Yr. 2 – $(1.5) million (f) Yr. 3 – $(1.5) million (f)
Other revenue sources		Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019 and 2020, the company recorded $2.6 million and $1.9 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively.
Revenue decoupling mechanisms	In 2015, 2016, 2017 and 2018, the company deferred for the customer’s benefit an immaterial amount, $6.3 million as regulatory liabilities, $11.2 million as regulatory asset and $0.5 million as regulatory asset, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million as regulatory assets.
Recoverable energy costs	Continuation of current rate recovery of purchased power costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential charges (up to $4 million annually) if certain performance targets are not met. In 2015 the company recorded $1.25 million in negative revenue adjustments. In 2016, 2017 and 2018, the company did not record any negative revenue adjustments.	Potential charges if certain performance targets relating to service, reliability and other matters are not met: Yr. 1 - $4.4 million Yr. 2 - $4.4 million Yr. 3 - $4.5 million In 2019 and 2020, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2015, 2016 and 2017, the company deferred $0.3 million, $7.4 million and $3.2 million as net decreases to regulatory assets, respectively. In 2018, the company deferred $5 million as a net regulatory asset.	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), major storms, the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $4.3 million and $30.3 million as net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates are: Yr. 1 – $928 million (c) Yr. 2 – $970 million (c) The company increased/(reduced) its regulatory asset by $2.2 million, $(1.9) million, $(1.9) million and $1.4 million in 2015, 2016, 2017 and 2018, respectively.	Target levels reflected in rates were: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $1,008 million Yr. 2 - $1,032 million Yr. 3 - $1,083 million AMI (j): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019 and deferred $0.4 million as a regulatory liability in 2020.
Average rate base	Yr. 1 – $763 million Yr. 2 – $805 million Yr. 3 – $805 million	Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent	Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent
Authorized return on common equity	9.0 percent	9.0 percent
Actual return on common equity (k)	Yr. 1 – 10.8 percent Yr. 2 – 9.7 percent Yr. 3 – 7.2 percent	Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent

136 CON EDISON ANNUAL REPORT 2020

Earnings sharing	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $6.1 million, $0.3 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold.
Cost of long-term debt	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent	Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent
Common equity ratio	48 percent	48 percent

(a)Rates determined pursuant to this rate plan continued in effect until the subsequent rate plan became effective.

(b)$59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a 5 year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015.

(c)Excludes electric AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2.

(d)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 (see Note T) are not necessary.

(e)The electric base rate increases shown above will be implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million.

(f)Reflects amortization of, among other things, the company’s net benefits under the TCJA prior to January 1, 2019, amortization of net regulatory liability for future income taxes and reduction of previously incurred regulatory assets for environmental remediation costs. Also, for electric, reflects amortization over a six year period of previously incurred incremental major storm costs. See "Other Regulatory Matters," below.

(g)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.

(h)Energy efficiency costs are expensed as incurred. Such costs are subject to a downward-only reconciliation over the terms of the electric and gas rate plans. The company will defer for the benefit of customers any cumulative shortfall over the terms of the electric and gas rate plans between actual expenditures and the levels provided in rates.

(i)In addition, amounts reflected in rates relating to income taxes and excess deferred federal income tax liability balances will be reconciled (i.e., refunded to or collected from customers) to any final, non-appealable NYSPSC-ordered findings in its investigation of O&R’s income tax accounting. See “Other Regulatory Matters,” in Note B.

(j)Net plant reconciliation for AMI expenditures will be implemented for a single category of AMI capital expenditures that includes amounts allocated to both electric and gas customers.

(k)Calculated in accordance with the earnings calculation method prescribed in the rate order.

In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective January 1, 2022, of $24.5 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased power, and the reconciliation of actual expenses allocable to the electric business to the amounts for such costs reflected in electric rates for storm costs, pension and other postretirement benefit costs, environmental remediation and property taxes.

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O&R New York – Gas
Effective period	November 2015 – October 2018 (a)	January 2019 – December 2021 (d)
Base rate changes	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge	Yr. 1 – $(7.5) million (e) Yr. 2 – $3.6 million (e) Yr. 3 – $0.7 million (e)
Amortization to income of net regulatory (assets) and liabilities	Yr. 1 – $(1.7) million (b) Yr. 2 – $(2.1) million (b) Yr. 3 – $(2.5) million (b)	Yr. 1 – $1.8 million (f) Yr. 2 – $1.8 million (f) Yr. 3 – $1.8 million (f)
Other revenue sources		Continuation of retention of annual revenues from non-firm customers of up to $4.0 million, with variances to be shared 80 percent by customers and 20 percent by company. Potential earnings adjustment mechanism incentives of up to $0.3 million annually. Potential incentives if performance targets related to gas leak backlog, leak prone pipe, emergency response, damage prevention and customer service are met: Yr. 1 - $1.2 million; Yr. 2 - $1.3 million; and Yr. 3 - $1.3 million. In 2019 and 2020, the company recorded $0.3 million of earnings adjustment mechanism incentives for energy efficiency. In 2019 and 2020, the company recorded $0.7 million and $0.5 million of positive incentives, respectively.
Revenue decoupling mechanisms	In 2015, 2016, 2017 and 2018, the company deferred $0.8 million of regulatory assets, $6.2 million of regulatory liabilities, $1.7 million of regulatory liabilities and $6.3 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2019 and 2020, the company deferred $0.8 million and $0.5 million of regulatory assets, respectively.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential charges (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $4.9 million in Yr. 3) if certain performance targets are not met. In 2015, 2016 and 2017, the company did not record any negative revenue adjustments. In 2018, the company recorded a $0.1 million negative revenue adjustment.	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $5.5 million; Yr. 2 - $5.7 million; and Yr. 3 - $6.0 million. In 2019 and 2020, the company recorded a $0.2 million and an immaterial amount of negative revenue adjustments, respectively.
Cost reconciliations	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively. In 2017 and 2018, the company deferred $3.5 million and $7.4 million as net regulatory liabilities, respectively.	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $6 million as net regulatory liabilities and $1.8 million as net regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates are: Yr. 1 – $492 million (c) Yr. 2 – $518 million (c) Yr. 3 – $546 million (c) No deferral was recorded for 2015 and immaterial amounts were recorded as regulatory liabilities in 2016 and 2017. In 2018, the company deferred $0.4 million as regulatory asset.	Target levels reflected in rates were: Gas average net plant target excluding AMI: Yr. 1 - $593 million Yr. 2 - $611 million Yr. 3 - $632 million AMI (j): Yr. 1 - $20 million Yr. 2 - $24 million Yr. 3 - $25 million In 2019 and 2020, the company deferred immaterial amounts as regulatory assets.
Average rate base	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million	Yr. 1 – $454 million Yr. 2 – $476 million Yr. 3 – $498 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent	Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent
Authorized return on common equity	9.0 percent	9.0 percent
Actual return on common equity (k)	Yr. 1 – 11.2 percent Yr. 2 – 9.7 percent Yr. 3 – 8.1 percent	Yr. 1 – 8.90 percent Yr. 2 – 9.58 percent

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Earnings sharing	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million, $0.2 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold.
Cost of long-term debt	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent	Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent
Common equity ratio	48 percent	48 percent

(a)Rates pursuant to this rate plan continued in effect until the subsequent rate plan became effective.

(b)Reflects that the company will not recover from customers a total of approximately $14 million of regulatory assets for property tax and interest rate reconciliations. Amounts that will not be recovered from customers were charged-off in June 2015.

(c)Excludes gas AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $0.5 million in year 1, $4.2 million in year 2 and $7.2 million in year 3.

(d)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 (see Note T) are not necessary.

(e)The gas base rate changes shown above will be implemented with changes of: Yr. 1 - $(5.9) million; Yr. 2 - $1.0 million; and Yr. 3 - $1.0 million.

(f)-(k) See footnotes (f) - (k) to the table under “O&R New York - Electric,” above.

In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for gas service rendered in New York, effective January 1, 2022, of $9.8 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased gas, and the reconciliation of actual expenses allocable to the gas business to the amounts for such costs reflected in gas rates for pension and other postretirement benefit costs, environmental remediation and property taxes.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 139

In January 2020, the NJBPU approved an electric rate increase, effective February 1, 2020, of $12 million for RECO. The following table contains a summary of the terms of the distribution rate plans.

RECO
Effective period	March 2017 – January 2020	February 2020
Base rate changes	Yr. 1 – $1.7 million	Yr. 1 – $12 million
Amortization to income of net regulatory (assets) and liabilities	$0.2 million over three years and continuation of $(25.6) million of deferred storm costs over four years which expired on July 31, 2018 (a)	$4.8 million over four years.
Recoverable energy costs	Current rate recovery of purchased power costs.	Current rate recovery of purchased power costs.
Cost reconciliations	None	None
Average rate base	Yr. 1 – $178.7 million	Yr. 1 – $229.9 million
Weighted average cost of capital (after-tax)	7.47 percent	7.11 percent
Authorized return on common equity	9.6 percent	9.5 percent
Actual return on common equity	Yr. 1 – 7.5 percent Yr. 2 – 5.7 percent	Yr. 1 – 5.4 percent
Cost of long-term debt	5.37 percent	4.88 percent
Common equity ratio	49.7 percent	48.32 percent

(a)In January 2016, the NJBPU approved RECO’s plan to spend $15.7 million in capital over three years to harden its electric system against storms, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge.

In November 2017, FERC approved a September 2017 settlement agreement among RECO, the New Jersey Division of Rate Counsel and the NJBPU that increases RECO's annual transmission revenue requirement from $11.8 million to $17.7 million, effective April 2017. The revenue requirement reflects a return on common equity of 10.0 percent.

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, 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 closed all non-essential businesses statewide. New York State designated utilities, including CECONY and O&R, as essential businesses that were able to continue a portion of their work during the effectiveness of the PAUSE order. In May 2020, the "New York Forward" plan went into effect. New York Forward is a phased plan to reopen businesses in geographic areas of New York State that meet metrics established by various public health organizations. In October 2020, Governor Cuomo announced a new cluster action initiative to address COVID-19 hotspots that have arisen in various areas of New York within the Utilities’ service territory and to impose new rules and restrictions targeted to areas with the highest concentration of COVID-19 cases and the surrounding communities. As a result of these COVID-19 clusters, the Utilities have limited their work in customer premises in the impacted areas to only address emergency, safety-related and selected service connections requested by customers. Since 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 during the COVID-19 state of emergency. In addition, such prohibition will apply for an additional 180 days after the state of emergency ends for residential customers who have experienced a change in financial circumstances due to the COVID-19 pandemic. The law expires on March 31, 2021, although legislation has been introduced to extend the expiration date until December 31, 2021 or later. For the year ended December 31, 2020, the estimated foregone revenues that were not collected by CECONY and O&R were approximately $61 million and $3 million, respectively (see Note M). Also in March 2020, the Utilities requested and the NYSPSC granted extensions to file their 2019 Earnings Adjustment Mechanisms (EAMs) reports, which were filed in July 2020. The earned EAM incentives of approximately $46 million and $3 million for CECONY

140 CON EDISON ANNUAL REPORT 2020

and O&R, respectively, are being recovered from customers over a twelve-month period that began September 2020.

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 cost of the program is being recovered over a five-year period that began January 2021. As of December 31, 2020, CECONY deferred for later recovery $63.4 million of summer cooling credit costs.

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. For the year ended December 31, 2020, the reserve increases to the allowance for uncollectible accounts associated with the COVID-19 pandemic for CECONY electric and gas operations and O&R electric operations were $73 million and $2 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. The reserve increase to the allowance for uncollectible accounts associated with the COVID-19 pandemic for O&R gas operations of $1 million did not meet the deferral threshold at December 31, 2020. 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 (due to the New York State on PAUSE and related executive orders), which differences were $18 million and $1 million for CECONY and O&R, respectively, for the year ended December 31, 2020.

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, NYSPSC staff 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 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.

In February 2021, the NYSPSC staff issued its report on New York State’s Energy Affordability Policy that provides recommendations to large New York utilities, including CECONY and O&R. 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 currently expires on March 31, 2021, although legislation has been introduced to extend the expiration to December 31, 2021 or later) 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 NYSPSC staff has requested that the utilities and interested parties comment on the report prior to staff submitting the recommendations to the NYSPSC for consideration.

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

The Utilities’ rate plans have revenue decoupling mechanisms in their New York electric and gas businesses that 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 and O&R New York’s electric customers and after the annual deferral period ends for CECONY 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.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 141

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. Since that declaration, 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 is not expected to be 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 through the later of September 30, 2021, or 60 days after the emergency declaration is no longer in effect. RECO deferred net incremental COVID-19 related costs of $0.5 million through December 31, 2020.

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. See footnote (d) to the CECONY - Electric and Gas tables under “Rate Plans,” above.

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. See "Rate Plans," above.

In January 2018, the NYSPSC issued an order initiating a focused operations audit of the income tax accounting of certain utilities, including CECONY and O&R. The Utilities are unable to estimate the amount or range of their possible loss related to this matter. At December 31, 2020, the Utilities had not accrued a liability related to this matter.

In March 2018, Winter Storms Riley and Quinn caused damage to the Utilities’ electric distribution systems and interrupted service to approximately 209,000 CECONY customers, 93,000 O&R customers and 44,000 RECO customers. At December 31, 2020, CECONY's costs related to March 2018 storms, including Riley and Quinn, amounted to $134 million, including operation and maintenance expenses reflected in its electric rate plan ($15 million), operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan ($84 million), capital expenditures ($29 million) and removal costs ($6 million). At December 31, 2020, O&R and RECO costs related to 2018 storms amounted to $43 million and $17 million, respectively, most of which were deferred as regulatory assets pursuant to their electric rate plans. In January 2019, O&R began recovering its deferred storm costs over a six-year period in accordance with its New York electric rate plan. In February 2020, RECO began recovering its deferred storm costs over a four-year period in accordance with its New Jersey electric

142 CON EDISON ANNUAL REPORT 2020

rate plan. The NYSPSC investigated the preparation and response to the storms by CECONY, O&R, and other New York electric utilities, including all aspects of their emergency response plans. In April 2019, following the issuance of a NYSPSC staff report on the investigation, the NYSPSC ordered the utilities to show cause why the NYSPSC should not commence a penalty action against them for violating their emergency response plans. During 2020, CECONY and O&R accrued $5.6 million and $0.85 million, respectively, related to this matter. In August 2020, the NYSPSC approved a July 2020 settlement agreement that provides for the Utilities to set aside $5.6 million and $0.85 million for the benefit of CECONY and O&R electric customers, respectively.

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. The NYSPSC has commenced an investigation. As of December 31, 2019, 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.

In March 2019, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence a penalty action and prudence proceeding against CECONY for alleged violations of gas operator qualification, performance, and inspection requirements. At December 31, 2019, the company had an accrued regulatory liability related to this matter of $10 million, and at March 31, 2020, the company accrued an additional regulatory liability of $5 million. In April 2020, the NYSPSC approved a $15 million settlement agreement for the benefit of CECONY’s gas customers between CECONY and NYSPSC staff related to this matter.

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. CECONY has not accrued any additional liability related to this matter and is unable to determine the outcome of this proceeding at this time.

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 December 31, 2020, CECONY incurred costs for Tropical Storm Isaias of $153 million (including $77 million of operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan, $58 million of capital expenditures and $18 million of operation and maintenance expenses). As of December 31, 2020, O&R incurred costs for Tropical Storm Isaias of $34 million (including $26 million of operation and maintenance expenses charged against a storm reserve pursuant to its New York electric rate plan and $8 million of capital expenditures). 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. In addition, as of December 31, 2020, CECONY and O&R incurred costs of $7.5 million and $2.9 million, respectively, for food and medicine spoilage claims. The provisions of the Utilities’ New York electric rate plans that impose negative revenue adjustments for operating

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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 New York State Department of Public Service (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. The Utilities have not accrued a liability related to this matter and are unable to determine the outcome of this proceeding at this time.

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. The Department of Energy is expected to issue regulations implementing the executive order. In January 2021, the president of the United States suspended the May 2020 executive order for 90 days. The Companies are unable to predict the impact on them of regulations that may be adopted regarding the bulk-power system.

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Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2020 and 2019 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Regulatory assets
Unrecognized pension and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	865	732	791	647
Revenue taxes	356	321	342	308
Pension and other postretirement benefits deferrals	315	71	272	47
Property tax reconciliation	241	219	239	210
Deferred storm costs	195	77	83	—
MTA power reliability deferral	188	248	188	248
System peak reduction and energy efficiency programs	124	131	124	130
Deferred derivative losses	120	83	111	76
COVID - 19 Deferrals	115	—	113	—
Municipal infrastructure support costs	62	75	62	75
Brooklyn Queens demand management program	36	39	36	39
Meadowlands heater odorization project	32	35	32	35
Gate station upgrade project	25	19	25	19
Unamortized loss on reacquired debt	21	28	19	26
Preferred stock redemption	21	22	21	22
Recoverable REV demonstration project costs	20	21	18	19
Non-wire alternative projects	18	14	18	14
Workers’ compensation	—	3	—	3
Other	200	180	186	166
Regulatory assets – noncurrent	6,195	4,859	5,745	4,487
Deferred derivative losses	190	128	177	113
Recoverable energy costs	76	—	67	—
Regulatory assets – current	266	128	244	113
Total Regulatory Assets	$6,461	$4,987	$5,989	$4,600
Regulatory liabilities
Future income tax*	$2,207	$2,426	$2,062	$2,275
Allowance for cost of removal less salvage	1,090	989	932	843
TCJA net benefits	295	471	286	454
Net unbilled revenue deferrals	198	199	198	199
Net proceeds from sale of property	137	173	137	173
Pension and other postretirement benefit deferrals	85	75	46	46
System benefit charge carrying charge	64	48	57	44
Property tax refunds	36	45	35	45
BQDM and REV Demo reconciliations	27	27	25	26
Settlement of gas proceedings	21	10	21	10
Sales and use tax refunds	16	8	16	8
Earnings sharing - electric, gas and steam	15	22	10	15
Unrecognized other postretirement costs	11	9	—	—
Settlement of prudence proceeding	5	8	5	8
Workers’ compensation	3	—	3	—
Energy efficiency portfolio standard unencumbered funds	1	122	—	118
Other	302	195	261	163
Regulatory liabilities – noncurrent	4,513	4,827	4,094	4,427
Refundable energy costs	28	44	4	12
Deferred derivative gains	8	34	7	34
Revenue decoupling mechanism	—	24	—	17
Regulatory liabilities—current	36	102	11	63
Total Regulatory Liabilities	$4,549	$4,929	$4,105	$4,490

* See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 145

MTA power reliability deferral represents CECONY’s costs in excess of those reflected in its prior electric rate plan to take certain actions relating to the electrical equipment that serves the Metropolitan Transportation Authority (MTA) subway system. The company is recovering this regulatory asset pursuant to its current electric rate plan. See footnote (d) to the CECONY - Electric table under “Rate Plans,” above.

Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Tropical Storm Isaias, Superstorm Sandy and other major storms that were deferred by the Utilities.

Settlement of prudence proceeding represents the remaining amount to be credited to customers pursuant to a Joint Proposal, approved by the NYSPSC in April 2016, with respect to the prudence of certain CECONY expenditures and related matters.

Settlement of gas proceedings represents the amount to be credited to customers pursuant to a settlement agreement approved by the NYSPSC in February 2017 related to CECONY’s practices of qualifying persons to perform plastic fusions on gas facilities and alleged violations of gas safety violations identified by the NYSPSC staff in its investigation of a March 2014 Manhattan explosion and fire (see Note H).

COVID - 19 Deferrals represents both the amount to be collected from customers related to the Emergency Summer Cooling Credits program for CECONY and amounts related to the increase in the allowance for uncollectible accounts resulting from the COVID-19 pandemic and New York on PAUSE and related executive orders, for electric and gas operations for CECONY and electric operations for O&R.

The NYSPSC has authorized CECONY to accrue unbilled electric, gas and steam revenues. CECONY has deferred the net margin on the unbilled revenues for the future benefit of customers by recording a regulatory liability of $198 million and $199 million at December 31, 2020 and 2019, respectively, for the difference between the unbilled revenues and energy cost liabilities.

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.

In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made ($1,696 million and $1,188 million for Con Edison, and $1,509 and $1,054 million for CECONY at December 31, 2020 and 2019, respectively). Regulatory liabilities are treated in a consistent manner. The Other Customer-Provided Capital rate for the years ended December 31, 2020 and 2019 was 2.65 percent and 4.2 percent, respectively. The recognition of the return on regulatory assets is determined by the Utilities’ rate plans or orders issued by state regulators.

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 December 31, 2020 and 2019, regulatory assets for Con Edison and CECONY that did not earn a return consisted of the following items:

146 CON EDISON ANNUAL REPORT 2020

Regulatory Assets Not Earning a Return

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Unrecognized and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	855	727	781	647
Revenue taxes	336	296	323	285
Deferred derivative losses	120	83	111	76
Workers' compensation	—	3	—	3
Other	24	21	24	20
Deferred derivative losses - current	190	128	177	112
Total	4,766	3,799	4,481	3,546

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 represent the 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.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 147

Note C – Capitalization

Common Stock

Con Edison is authorized to issue 500,000,000 shares of its common stock and CECONY is authorized to issue 340,000,000 of its common stock. At December 31, 2020 and 2019, 342,297,534 and 332,629,597 shares, respectively, of Con Edison common stock were outstanding. At December 31, 2020 and 2019, 235,488,094 million shares of CECONY common stock were outstanding, all of which were owned by Con Edison. At December 31, 2020 and 2019, Con Edison had 23,210,700 treasury shares, including 21,976,200 shares of Con Edison stock that CECONY purchased prior to 2001 in connection with Con Edison’s stock repurchase plan. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity.

In May 2019, Con Edison entered into a forward sale agreement relating to 5,800,000 shares of its common stock. In June 2019, the company issued 4,750,000 shares for $400 million upon physical settlement of shares subject to the forward sale agreement. In January 2020, the company issued 1,050,000 shares for $88 million upon physical settlement of the remaining shares subject to the forward sale agreement.

In December 2020, Con Edison issued 7,200,000 shares of its common stock resulting in net proceeds of approximately $553 million, after issuance expenses. The net proceeds from the sale of the common shares, together with the net proceeds from the sale of $650 million aggregate principal amount of 0.65 percent debentures due 2023, were used to prepay in full a $820 million July 2020 term loan. The remaining net proceeds from the sale of the common shares were invested by Con Edison in its subsidiaries, principally CECONY and O&R, and for other general corporate purposes.

Capitalization of Con Edison

Con Edison's capitalization shown on its Consolidated Statement of Capitalization includes its outstanding common stock and long-term debt and the outstanding long-term debt of the Utilities and the Clean Energy Businesses.

Dividends

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

Long-term Debt

Long-term debt maturing in the period 2021-2025 is as follows:

(Millions of Dollars)	Con Edison	CECONY
2021	$1,967	$640
2022	437	—
2023	966	—
2024	385	250
2025	315	—

CECONY has issued $450 million of tax–exempt debt through the New York State Energy Research and Development Authority (NYSERDA) that currently bear interest at a rate determined weekly and is subject to tender by bondholders for purchase by the company.

The carrying amounts and fair values of long-term debt at December 31, 2020 and 2019 are:

(Millions of Dollars)	2020		2019
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$22,349	$26,808	$19,973	$22,738
CECONY	$16,789	$20,974	$14,964	$17,505

148 CON EDISON ANNUAL REPORT 2020

(a)Amounts shown are net of unamortized debt expense and unamortized debt discount of $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020 and $178 million and $151 million for Con Edison and CECONY, respectively, as of December 31, 2019.

The fair values of the Companies' long-term debt have been estimated primarily using available market information and at December 31, 2020 are classified as Level 2 (see Note Q).

Significant Debt Covenants

The significant debt covenants under the financing arrangements for the Companies' debentures and Con Edison's notes and February 2019 $825 million ($675 million of which was outstanding at December 31, 2020) variable-rate term loan that matures in June 2021 include obligations to pay principal and interest when due and covenants not to consolidate with or merge into any other entity unless certain conditions are met. In addition, the notes include a covenant that the company shall continue its utility business in New York City, the term loan includes a covenant that, subject to certain exceptions, the company and its subsidiaries will not mortgage, lien, pledge or otherwise encumber its assets, and the notes and term loan provide that the company shall not permit its ratio of consolidated debt to consolidated total capital to exceed certain amounts (0.675 to 1 for the notes and 0.65 for the term loan) and include cross default provisions with respect to the failure by the company or any material subsidiary to make one or more payments in respect of material financial obligations (in excess of an aggregate $100 million of debt for the notes and $150 million of debt or derivative obligations for the term loan, excluding non-recourse debt) of the company (or any of its material subsidiaries, in the case of the notes) and the occurrence of an event or condition which results in the acceleration of the maturity of any material debt (in excess of an aggregate $100 million for the notes and $150 million for the term loan, not including non-recourse debt) of the company (or any of its material subsidiaries, in the case of the notes) or enables the holders of such debt to accelerate the maturity thereof. The Companies' debentures have no cross default provisions. The tax–exempt financing arrangements of CECONY are subject to covenants for the debentures discussed above and the covenants discussed below. The Companies were in compliance with their significant debt covenants at December 31, 2020.

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

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

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

Note D – Short-Term Borrowing

In December 2016, Con Edison and the Utilities entered into a credit agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis. The Credit Agreement, as amended in 2019, expires in December 2023. There is a maximum of $2,250 million of credit available through December 2022 and $2,200 million of credit available from then through December 2023. The full amount is available to CECONY and $1,000 million (subject to increase up to $1,500 million) is available to Con Edison, including up to $1,200 million of letters of credit. The Credit Agreement supports the Companies’ commercial paper programs. The Companies have not borrowed under the Credit Agreement. At December 31, 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 December 31, 2019, Con Edison had $1,692 million of commercial paper outstanding of which $1,137 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2019 was 2.0 percent for both Con Edison and CECONY.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 149

At December 31, 2020 and 2019, no loans were outstanding under the Credit Agreement. An immaterial amount of letters of credit were outstanding under the Credit Agreement as of December 31, 2020 and 2019.

The banks’ commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default for a company include that company exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2020 this ratio was 0.53 to 1 for Con Edison and 0.56 to 1 for CECONY); that company having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, subject to certain exceptions; that company or any of its material subsidiaries failing to make one or more payments in respect of material financial obligations (in excess of an aggregate $150 million of debt or derivative obligations other than non-recourse debt) of that company; the occurrence of an event or condition which results in the acceleration of the maturity of any material debt (in excess of an aggregate $150 million of debt other than non-recourse debt) of that company or enables the holders of such debt to accelerate the maturity thereof; and other customary events of default. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings. The Companies were in compliance with their covenants at December 31, 2020.

In December 2020, a subsidiary of the Clean Energy Businesses borrowed $165 million under a $613 million variable-rate construction loan facility that matures no later than November 2021, (the Construction Loan Facility) and that is secured by and was used to fund construction costs for three of the company’s solar electric production projects. The banks’ commitments under the Construction Loan Facility are subject to certain conditions, including, among other customary conditions, demonstration of construction progress, that there be no event of default and no material adverse effect. The subsidiary of the Clean Energy Businesses was in compliance with its covenants at December 31, 2020.

See Note T for information about short-term borrowing between related parties.

Note E – Pension Benefits

Con Edison maintains a tax-qualified, non-contributory pension plan that covers substantially all employees of CECONY, O&R and Con Edison Transmission and certain employees of the Clean Energy Businesses. The plan is designed to comply with the Internal Revenue Code and the Employee Retirement Income Security Act of 1974. Con Edison also maintains additional non–qualified supplemental pension plans.

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit costs for 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Service cost – including administrative expenses	$293	$250	$290	$274	$232	$272
Interest cost on projected benefit obligation	549	601	561	515	564	525
Expected return on plan assets	(1,034)	(988)	(1,033)	(980)	(936)	(979)
Recognition of net actuarial loss	699	518	688	661	492	651
Recognition of prior service credit	(16)	(17)	(17)	(19)	(19)	(19)
TOTAL PERIODIC BENEFIT COST	$491	$364	$489	$451	$333	$450
Cost capitalized	(130)	(108)	(127)	(123)	(102)	(119)
Reconciliation to rate level	(250)	(15)	(92)	(239)	(12)	(100)
Total expense recognized	$111	$241	$270	$89	$219	$231

In March 2017, the FASB issued amendments to the guidance for retirement benefits through ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The Companies adopted ASU 2017-07 beginning on January 1, 2018. The

150 CON EDISON ANNUAL REPORT 2020

guidance requires that components of net periodic benefit cost other than service cost be presented outside of operating income on consolidated income statements, and that only the service cost component is eligible for capitalization. Accordingly, the service cost components are 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. In August 2018, the FASB issued amendments to the guidance for retirement benefits through ASU 2018-14, “Compensation-Retirement Benefits (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans." The guidance requires disclosure of the weighted-average interest crediting rate used for cash balance plans for all periods presented, and a narrative description of significant changes in the benefit obligation. The Companies adopted ASU 2018-14 for fiscal years ending after December 15, 2020 and the required disclosures are included below and, as applicable, in Note F.

Funded Status

The funded status at December 31, 2020, 2019 and 2018 was as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$16,792	$14,449	$15,536	$15,750	$13,542	$14,567
Service cost – excluding administrative expenses	288	245	286	269	228	267
Interest cost on projected benefit obligation	549	601	561	515	564	525
Net actuarial loss/(gain)	2,281	2,191	(1,219)	2,154	2,076	(1,159)
Plan amendments	—	15	—	—	—	—
Benefits paid	(945)	(709)	(715)	(867)	(660)	(658)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$18,965	$16,792	$14,449	$17,821	$15,750	$13,542
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$15,608	$13,450	$14,274	$14,790	$12,744	$13,519
Actual return on plan assets	1,927	2,556	(536)	1,830	2,425	(507)
Employer contributions	475	350	473	435	318	434
Benefits paid	(945)	(709)	(715)	(867)	(660)	(658)
Administrative expenses	(43)	(39)	(46)	(41)	(37)	(44)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$17,022	$15,608	$13,450	$16,147	$14,790	$12,744
FUNDED STATUS	$(1,943)	$(1,184)	$(999)	$(1,674)	$(960)	$(798)
Unrecognized net loss	$3,330	$2,604	$2,464	$3,145	$2,466	$2,338
Unrecognized prior service costs/(credits)	(156)	(173)	(205)	(183)	(202)	(222)
Accumulated benefit obligation	16,768	15,015	13,030	15,676	14,010	12,161

The increase in the pension funded status liability at December 31, 2020 for Con Edison and CECONY of $759 million and $714 million, respectively, compared with December 31, 2019, was primarily due to an increase in the plan's projected benefit obligation as a result of a decrease in the discount rate. The increase in the pension funded status liability at December 31, 2019 for Con Edison and CECONY of $185 million and $162 million, respectively, compared with December 31, 2018, was primarily due to an increase in the plan’s projected benefit obligation as a result of a decrease in the discount rate, partially offset by an increase in plan assets as a result of the actual return on plan assets. See below for further information on the change in the discount rate and determination of the discount rate assumption. For Con Edison, the 2020 increase in pension funded status liability corresponds with an increase to regulatory assets of $734 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, a debit to OCI of $8 million (net of taxes) for the unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of the Clean Energy Businesses, Con Edison Transmission, and RECO who previously worked for the Utilities.

For CECONY, the increase in the pension funded status liability at December 31, 2020 corresponds with an increase to regulatory assets of $696 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, and also a debit to OCI of $2 million (net of taxes) for unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of the Clean Energy Businesses and Con Edison Transmission who previously worked for CECONY.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 151

At December 31, 2020 and 2019, Con Edison’s investments included $465 million and $397 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $439 million and $371 million, respectively. See Note Q. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $414 million and $377 million as of December 31, 2020, respectively, and $395 million and $360 million as of December 31, 2019, respectively.

Assumptions

The actuarial assumptions were as follows: 

	2020		2019		2018
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate	2.55	%	3.35	%	4.25	%
Interest crediting rate for cash balance plan	3.00	%	3.30	%	4.00	%
Rate of compensation increase
CECONY	3.80	%	3.80	%	4.25	%
O&R	3.20	%	3.20	%	4.00	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	3.35	%	4.25	%	3.70	%
Interest crediting rate for cash balance plan	3.30	%	4.00	%	4.10	%
Expected return on plan assets	7.00	%	7.00	%	7.50	%
Rate of compensation increase
CECONY	3.80	%	4.25	%	4.25	%
O&R	3.20	%	4.00	%	4.00	%

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

Discount Rate Assumption

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

Expected Benefit Payments

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

(Millions of Dollars)	2021	2022	2023	2024	2025	2026-2030
Con Edison	$764	$776	$793	$807	$821	$4,295
CECONY	706	718	733	747	760	3,992

Expected Contributions

Based on estimates as of December 31, 2020, the Companies expect to make contributions to the pension plans during 2021 of $480 million (of which $441 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.

152 CON EDISON ANNUAL REPORT 2020

Plan Assets

The asset allocations for the pension plan at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2021	2020		2019		2018
Equity Securities	45% - 55%	51	%	51	%	51	%
Debt Securities	33% - 43%	38	%	38	%	39	%
Real Estate	10% - 14%	11	%	11	%	10	%
Total	100%	100	%	100	%	100	%

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

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

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

The strategic asset allocation is intended to meet the objectives of the pension plan by diversifying its funds across asset classes, investment styles and fund managers. An asset/liability study typically is conducted every few years to determine whether the current strategic asset allocation continues to represent the appropriate balance of expected risk and reward for the plan to meet expected liabilities. Each study considers the investment risk of the asset allocation and determines the optimal asset allocation for the plan. The target asset allocation for 2021 reflects the results of such a study conducted in 2018.

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

Assets measured at fair value on a recurring basis are summarized below as defined by the accounting rules for fair value measurements (see Note Q).

                                                                                                                         CON EDISON ANNUAL REPORT 2020 153

The fair values of the pension plan assets at December 31, 2020 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Investments within the fair value hierarchy
U.S. Equity (a)	$4,202	$—	$4,202
International Equity (b)	3,693	—	3,693
U.S. Government Issued Debt (c)	—	1,424	1,424
Corporate Bonds Debt (d)	—	3,535	3,535
Structured Assets Debt (e)	—	188	188
Other Fixed Income Debt (f)	—	1,067	1,067
Cash and Cash Equivalents (g)	51	408	459
Total investments within the fair value hierarchy	$7,946	$6,622	$14,568
Investments measured at NAV per share (m)
Private Equity (h)			635
Real Estate (i)			1,880
Hedge Funds (j)			292
Total investments valued using NAV per share			$2,807
Funds for retiree health benefits (k)	(116)	(97)	(213)
Funds for retiree health benefits measured at NAV per share (k)(m)			(41)
Total funds for retiree health benefits			$(254)
Investments (excluding funds for retiree health benefits)	$7,830	$6,525	$17,121
Pending activities (l)			(99)
Total fair value of plan net assets			$17,022

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

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

(c)U.S. Government Issued Debt includes agency and treasury securities.

(d)Corporate Bonds Debt consists of debt issued by various corporations.

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

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

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

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

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

(j)Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.

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

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

(m)In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy.

154 CON EDISON ANNUAL REPORT 2020

The fair values of the pension plan assets at December 31, 2019 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,652	$—	$3,652
International Equity (b)	3,354	—	3,354
U.S. Government Issued Debt (c)	—	1,496	1,496
Corporate Bonds Debt (d)	—	3,260	3,260
Structured Assets Debt (e)	—	173	173
Other Fixed Income Debt (f)	—	955	955
Cash and Cash Equivalents (g)	—	326	326
Total investments within the fair value hierarchy	$7,006	$6,210	$13,216
Investments measured at NAV per share (m)
Private Equity (h)			555
Real Estate (i)			1,806
Hedge Funds (j)			270
Total investments valued using NAV per share			$2,631
Funds for retiree health benefits (k)	(110)	(98)	(208)
Funds for retiree health benefits measured at NAV per share (k)(m)			(42)
Total funds for retiree health benefits			$(250)
Investments (excluding funds for retiree health benefits)	$6,896	$6,112	$15,597
Pending activities (l)			11
Total fair value of plan net assets			$15,608

(a) - (m) Reference is made to footnotes (a) through (m) in the above table of pension plan assets at December 31, 2020 by asset category.

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

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$52	$49	$45
CECONY	43	42	39

Note F – Other Postretirement Benefits

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

CECONY also has a contributory life insurance program for bargaining unit employees and provides basic life insurance benefits up to a specified maximum at no cost to certain retired management employees. O&R has a non-contributory life insurance program for retirees. Certain employees of the Clean Energy Businesses and Con Edison Transmission are eligible to receive benefits under these programs.

Total Periodic Benefit Cost

The components of the Companies’ total periodic postretirement benefit costs for 2020, 2019 and 2018 were as follows:

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	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Service cost	$21	$18	$20	$16	$13	$14
Interest cost on accumulated other postretirement benefit obligation	37	44	42	31	36	34
Expected return on plan assets	(66)	(66)	(73)	(54)	(54)	(63)
Recognition of net actuarial loss/(gain)	37	(9)	8	36	(10)	3
Recognition of prior service credit	(3)	(2)	(6)	(2)	(2)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	$26	$(15)	$(9)	$27	$(17)	$(14)
Cost capitalized	(9)	(7)	(8)	(7)	(5)	(6)
Reconciliation to rate level	(17)	12	8	(25)	7	9
Total credit recognized	$—	$(10)	($9)	$(5)	$(15)	($11)

For information about the adoption of ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” and ASU 2018-14, “Compensation-Retirement Benefits (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans," see Note E.

Funded Status

The funded status of the programs at December 31, 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$1,357	$1,114	$1,219	$1,154	$913	$985
Service cost	21	18	20	16	13	14
Interest cost on accumulated postretirement benefit obligation	37	44	42	31	36	34
Amendments	—	(14)	—	—	—	—
Net actuarial loss/(gain)	74	264	(70)	63	252	(32)
Benefits paid and administrative expenses, net of subsidies	(117)	(110)	(135)	(107)	(100)	(125)
Participant contributions	53	41	38	52	40	37
BENEFIT OBLIGATION AT END OF YEAR	$1,425	$1,357	$1,114	$1,209	$1,154	$913
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$1,026	$885	$1,039	$872	$759	$893
Actual return on plan assets	142	198	(66)	117	165	(54)
Employer contributions	7	7	6	4	6	6
Employer group waiver plan subsidies	20	23	34	19	22	32
Participant contributions	53	40	37	51	40	37
Benefits paid	(133)	(127)	(165)	(123)	(120)	(155)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$1,115	$1,026	$885	$940	$872	$759
FUNDED STATUS	$(310)	$(331)	$(229)	$(269)	$(282)	$(154)
Unrecognized net loss/(gain)	$115	$155	$14	$114	$149	$(2)
Unrecognized prior service costs	(16)	(19)	(8)	(1)	(3)	(5)

The decrease in the other postretirement benefits funded status liability at December 31, 2020 for Con Edison and CECONY of $21 million and $13 million, respectively, compared with December 31, 2019, was primarily due to an increase in the fair value of plan assets as a result of the actual return on plan assets, partially offset by an increase in the plans' projected benefit obligation as a result of a decrease in the discount rate. See below for further information on the change in the discount rate and see Note E for determination of the discount rate assumption. The increase in the other postretirement benefits funded status liability at December 31, 2019 for Con Edison and CECONY of $102 million and $128 million, respectively, compared with December 31, 2018, was primarily due to an

156 CON EDISON ANNUAL REPORT 2020

increase in the plans' projected benefit obligation as a result of an increase in net actuarial loss, partially offset by an increase in plan assets as a result of the actual return on plan assets.

For Con Edison, the decrease in funded status liability at December 31, 2020 corresponds with a net decrease to regulatory assets of $36 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, a credit to OCI of $2 million (net of taxes) for the unrecognized net losses and an immaterial change to OCI for the unrecognized prior service costs associated with the Clean Energy Businesses, Con Edison Transmission, and RECO.

For CECONY, the decrease in funded status liability at December 31, 2020 corresponds with a decrease to regulatory assets of $33 million for unrecognized net losses and the unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, and immaterial changes to OCI for the unrecognized net losses and the unrecognized prior service costs associated with eligible employees of the Clean Energy Businesses and Con Edison Transmission who previously worked for CECONY.

Assumptions

The actuarial assumptions were as follows: 

	2020		2019		2018
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY	2.25	%	3.10	%	4.15	%
O&R	2.55	%	3.35	%	4.30	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate
CECONY	3.10	%	4.15	%	3.55	%
O&R	3.35	%	4.30	%	3.70	%
Expected Return on Plan Assets	6.80	%	6.80	%	7.50	%

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

The health care cost trend rate used to determine net periodic benefit cost for the years ended December 31, 2020, 2019 and 2018 was 5.20 percent, 5.40 percent and 5.60 percent, respectively, which was assumed to decrease gradually to 4.50 percent by 2024 and remain at that level thereafter. The health care cost trend rate used to determine benefit obligations as of December 31, 2020, 2019 and 2018 was 7.04 percent, 5.20 percent and 5.40 percent, respectively, which is assumed to decrease gradually to 4.50 percent by 2034 and remain at that level thereafter.

Expected Benefit Payments

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

(Millions of Dollars)	2021	2022	2023	2024	2025	2026-2030
Con Edison	$84	$84	$84	$84	$84	$409
CECONY	76	75	75	75	75	358

Expected Contributions

Based on estimates as of December 31, 2020, Con Edison and CECONY expect to make a contribution of $6 million (of which $3 million is expected to be made by CECONY) to the other postretirement benefit plans in 2021. The Companies’ policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

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Plan Assets

The asset allocations for CECONY’s other postretirement benefit plans at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2021	2020		2019		2018
Equity Securities	42%-80%	54	%	54	%	52	%
Debt Securities	20%-58%	46	%	46	%	48	%
Total	100%	100	%	100	%	100	%

Con Edison has established postretirement health and life insurance benefit plan trusts for the investment of assets to be used for the exclusive purpose of providing other postretirement benefits to participants and beneficiaries.

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

The fair values of the plans' assets at December 31, 2020 by asset category as defined by the accounting rules for fair value measurements (see Note Q) are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Equity (a)	$—	$448	$448
Other Fixed Income Debt (b)	—	367	367
Cash and Cash Equivalents (c)	—	27	27
Total investments	$—	$842	$842
Funds for retiree health benefits (d)	116	97	213
Investments (including funds for retiree health benefits)	$116	$939	$1,055
Funds for retiree health benefits measured at net asset value (d)(e)			41
Pending activities (f)			19
Total fair value of plan net assets			$1,115

(a)Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index.

(b)Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index.

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

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

(e)In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy.

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

158 CON EDISON ANNUAL REPORT 2020

The fair values of the plans' assets at December 31, 2019 by asset category (see Note Q) are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Equity (a)	$—	$404	$404
Other Fixed Income Debt (b)	—	331	331
Cash and Cash Equivalents (c)	—	23	23
Total investments	$—	$758	$758
Funds for retiree health benefits (d)	110	98	208
Investments (including funds for retiree health benefits)	$110	$856	$966
Funds for retiree health benefits measured at net asset value (d)(e)			42
Pending activities (f)			18
Total fair value of plan net assets			$1,026

(a) - (f) Reference is made to footnotes (a) through (f) in the above table of other postretirement benefit plan assets at December 31, 2020 by asset category.

Note G – Environmental Matters

Superfund Sites

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

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

For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of 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 December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Accrued Liabilities:
Manufactured gas plant sites	$752	$640	$676	$561
Other Superfund Sites	105	94	104	93
Total	$857	$734	$780	$654
Regulatory assets	$865	$732	$791	$647

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 159

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 at December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Remediation costs incurred	$33	$19	$32	$13

Insurance and other third party recoveries received by Con Edison or CECONY were immaterial in 2020 and 2019.

Con Edison and CECONY estimate that in 2021 they will incur costs for remediation of approximately $40 million and $38 million, respectively. The Companies are unable to estimate the time period over which the remaining accrued liability will be incurred because, among other things, the required remediation has not been determined for some of the sites.

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 $2,700 million and $2,600 million, 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 December 31, 2020, Con Edison and CECONY have accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. These estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Courts have begun, and unless otherwise determined on appeal may continue, to apply different standards for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims.

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$72	$78	$68	$73
Regulatory assets/(liabilities) – workers’ compensation	$(3)	$3	$(3)	$3

160 CON EDISON ANNUAL REPORT 2020

Note H – 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 October 2020, the company accrued a $40 million liability for damages and a $40 million insurance receivable related to the incident.

For information about material contingencies, see “Other Regulatory Matters” in Note B, “Superfund Sites” and “Asbestos Proceedings” in Note G and "Uncertain Tax Positions" in Note L.

Con Edison and its subsidiaries have entered into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison under these agreements totaled $2,042 million and $1,831 million at December 31, 2020 and 2019, respectively.

A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2020 is as follows:

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years	Total
	(Millions of Dollars)
Con Edison Transmission	$393	$177	$—	$570
Energy transactions	480	51	222	753
Renewable electric production projects	285	9	355	649
Other	70	—	—	70
Total	$1,228	$237	$577	$2,042

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.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 161

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 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 – Electricity Purchase Agreements

The Utilities have electricity purchase agreements with non-utility generators and others for generating capacity. The Utilities recover their purchased power costs in accordance with provisions approved by the applicable state public utility regulators. See “Recoverable Energy Costs” in Note A. The Utilities also conducted auctions and have entered into various other electricity purchase agreements. Assuming performance by the parties to the electricity purchase agreements, the Utilities are obligated over the terms of the agreements to make capacity and other fixed payments.

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

(Millions of Dollars)	2021	2022	2023	2024	2025	All Years Thereafter
Con Edison	$141	$106	$68	$53	$54	$487
CECONY	138	106	68	53	54	487

For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the significant terms of the agreements for capacity, energy and other fixed payments in 2020, 2019 and 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Indian Point (a)	$—	$—	$6
Astoria Generating Company (b)	26	116	179
Brooklyn Navy Yard (c)	113	115	124
Cogen Technologies	—	—	9
Total	$139	$231	$318

(a) Contract term ended in 2018.

(b) Capacity purchase agreements with terms ending in 2020 and 2023.

(c) Contract for plant output, which started in 1996 and ends in 2036.

162 CON EDISON ANNUAL REPORT 2020

Note J – Leases

In January 2019, the Companies adopted Accounting Standards Update (ASU) No. 2016-02, “Leases (Topic 842),” including the amendments thereto, using a modified retrospective transition method of adoption that required no prior period adjustments or charges to retained earnings for cumulative impact. The standard supersedes the lease requirements within ASC Topic 840, “Leases.” The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognized lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases.

For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 40 years and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. The Companies account for lease and non-lease components as a single lease component.

Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the twelve months ended December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Operating lease cost	$85	$83	$65	$64
Operating lease cash flows	$79	$75	$61	$60

As of December 31, 2020, assets recorded as finance leases for Con Edison and CECONY were $3 million and $2 million, respectively, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively. As of December 31, 2019, assets recorded as finance leases were $1 million for Con Edison and an immaterial amount for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $5 million and $3 million, respectively.

For the twelve months ended December 31, 2020 and 2019, finance lease costs and cash flows for Con Edison and CECONY were immaterial.

Right-of-use assets obtained in exchange for lease obligations for Con Edison and CECONY were $23 million and $11 million, respectively, for the twelve months ended December 31, 2020 and $39 million and $4 million, respectively, for the twelve months ended December 31, 2019.

Other information related to leases for Con Edison and CECONY at December 31, 2020 and 2019 was as follows:

                                                                                                                         CON EDISON ANNUAL REPORT 2020 163

	Con Edison		CECONY
	2020	2019	2020	2019
Weighted Average Remaining Lease Term:
Operating leases	19.1 years	19.8 years	13.0 years	14.0 years
Finance leases	7.3 years	12.2 years	4.0 years	2.4 years
Weighted Average Discount Rate:
Operating leases	4.3%	4.3%	3.6%	3.6%
Finance leases	1.8%	3.5%	1.3%	4.1%

Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending December 31,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2021	$79	$1	$62	$1
2022	77	1	58	1
2023	74	—	57	—
2024	75	—	57	—
2025	75	—	58	—
All years thereafter	938	1	451	—
Total future minimum lease payments	$1,318	$3	$743	$2
Less: imputed interest	(458)	—	(158)	—
Total	$860	$3	$585	$2
Reported as of December 31, 2020
Operating lease liabilities (current)	$96	$—	$73	$—
Operating lease liabilities (noncurrent)	764	—	512	—
Other current liabilities	—	1	—	1
Other noncurrent liabilities	—	2	—	1
Total	$860	$3	$585	$2

At December 31, 2020, 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 twelve months ended December 31, 2020 and 2019.

Note K – Goodwill

The Companies test goodwill for impairment at least annually or whenever there is a triggering event. There is an option to first make a qualitative assessment of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount before applying a quantitative goodwill impairment test. The quantitative goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment loss shall be recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit.

164 CON EDISON ANNUAL REPORT 2020

Con Edison has recorded goodwill related to the O&R merger, the acquisition of a gas storage company by CET Gas, and the acquisitions of a residential solar company and battery storage company by the Clean Energy Businesses. In 2020 and 2019, Con Edison completed impairment tests for their goodwill of $406 million related to the O&R merger and determined that it was not impaired. For the impairment test, $245 million and $161 million of goodwill were allocated to CECONY and O&R, respectively. In 2019, the Companies performed the optional qualitative assessment for goodwill related to the O&R merger. In 2020 and 2019, Con Edison completed impairment tests for goodwill of $8 million related to the gas storage company acquired by CET Gas, $14 million related to the residential solar company acquired by the Clean Energy Businesses and $18 million related to the battery storage company acquired by the Clean Energy Businesses, and determined that they were not impaired. Estimates of future cash flows, projected growth rates, and discount rates inherent in the cash flow estimates for Con Edison subsidiaries other than the Utilities may vary significantly from actual results, which could result in a future impairment of goodwill. 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 may not be recoverable at December 31, 2020.

Note L – Income Tax

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 was carried back to tax year 2013, which had a 35 percent federal statutory tax rate. This income tax benefit was primarily recognized at the Clean Energy Businesses.

The components of income tax are as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
State
Current	$7	$(12)	$(10)	$6	$22	$6
Deferred	50	96	107	97	68	82
Federal
Current	(2)	—	3	41	185	(34)
Deferred	42	219	310	73	63	275
Amortization of investment tax credits	(7)	(7)	(9)	(2)	(3)	(3)
Total income tax expense	$90	$296	$401	$215	$335	$326

                                                                                                                         CON EDISON ANNUAL REPORT 2020 165

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

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Deferred tax liabilities:
Property basis differences	$7,985	$7,699	$6,901	$6,640
Regulatory assets:
Unrecognized pension and other postretirement costs	910	712	861	674
Environmental remediation costs	243	205	222	181
Deferred storm costs	31	22	—	—
Other regulatory assets	536	376	508	355
Operating lease right-of-use asset	220	231	165	169
Equity investments	46	104	—	—
Total deferred tax liabilities	$9,971	$9,349	$8,657	$8,019
Deferred tax assets:
Accrued pension and other postretirement costs	$504	$291	$427	$222
Regulatory liabilities:
Future income tax	617	678	579	638
Other regulatory liabilities	656	702	570	622
Superfund and other environmental costs	241	206	219	183
Asset retirement obligations	178	135	143	102
Operating lease liabilities	211	231	165	170
Loss carryforwards	164	108	34	—
Tax credits carryforward	1,022	896	—	—
Valuation allowance	(22)	(31)	—	—
Other	59	47	127	103
Total deferred tax assets	3,630	3,263	2,264	2,040
Net deferred tax liabilities	$6,341	$6,086	$6,393	$5,979
Unamortized investment tax credits	134	141	18	21
Net deferred tax liabilities and unamortized investment tax credits	$6,475	$6,227	$6,411	$6,000

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

	Con Edison						CECONY
(% of Pre-tax income)	2020		2019		2018		2020		2019		2018
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	4		4		4		5		5		5
Taxes attributable to noncontrolling interests	(1)		(1)		—		—		—		—
Cost of removal	2		1		1		1		1		1
Other plant-related items	(1)		(1)		(1)		(1)		(1)		(1)
TCJA deferred tax re-measurement	—		—		2		—		—		—
Amortization of excess deferred federal income taxes	(14)		(4)		(3)		(12)		(4)		(3)
Renewable energy credits	(3)		(2)		(1)		—		—		—
Research and development credits	—		(1)		—		—		(1)		(1)
Other	(1)		—		—		1		—		(1)
Effective tax rate	7	%	17	%	23	%	15	%	21	%	21	%

166 CON EDISON ANNUAL REPORT 2020

CECONY and O&R deferred as regulatory liabilities their estimated net benefits under the TCJA for the year ended December 31, 2018. CECONY’s net benefits prior to January 1, 2019 for its electric service and amortization of excess deferred federal income taxes for its electric service continued to be deferred. RECO deferred as a regulatory liability its estimated net benefits under the TCJA for the three months ended March 31, 2018. The net benefits include the revenue requirement impact of the reduction in the corporate federal income tax rate to 21 percent, the elimination for utilities of bonus depreciation and the amortization of excess deferred federal income taxes the utilities collected from customers that will not be paid to the IRS under the TCJA. See “Other Regulatory Matters” in Note B.

At December 31, 2020, Con Edison has a federal NOL of approximately $21 million that can be carried forward indefinitely. Con Edison also has $1,022 million in general business tax credit carryovers (primarily renewable energy tax credits), which if unused will begin to expire in 2032. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance was provided, as it is more likely than not that the deferred tax asset will be realized.

At December 31, 2020, Con Edison has a New York State NOL of approximately $1,351 million, primarily as a result of higher accelerated state tax depreciation. A deferred tax asset has been recognized for these New York State NOL carryforwards that will begin to expire, if unused, in 2039 and no valuation allowance was provided; as it is more likely than not that the deferred tax asset will be realized. In addition, Con Edison reversed $9 million of the valuation allowance against the New York City NOL deferred tax asset that will be realized over the next 10 years. Con Edison also has a $18 million valuation allowance for other state NOL carryforwards; as it is not more likely than not that the deferred tax asset will be realized.

The Protecting Americans from Tax Hikes Act of 2015 extended bonus depreciation applying a 50 percent rate for property acquired and placed in service for years 2015 through 2017 with reduced rates of 40 percent and 30 percent for years 2018 and 2019, respectively. The TCJA does not allow bonus depreciation after December 31, 2017 (excluding certain transition rules) for Companies that qualify as a utility company for the consolidated group under the de minimis exception to Treasury regulations.

In December 2019, the Federal government issued final regulations providing guidance on provisions in the TCJA allowing for full expensing of qualified plant additions. These provisions, which Con Edison adopted under the proposed regulations of August 2018, allowed the Utilities a full expense tax deduction for plant additions in the fourth quarter of 2017, and the Utilities continue additional first year depreciation transition rules for plant additions placed in service in tax years beginning in 2018, under long-term construction contracts entered into before September 28, 2017. The impact on the Utilities of these regulations is discussed above.

In November 2018, the Federal government issued, and Con Edison adopted, proposed regulations providing guidance on the tax deductibility of interest expense under the TCJA. The TCJA generally provides for the continued deductibility of interest expense by regulated public utilities and may limit the deduction for interest expense by most non-utility businesses to 30 percent of adjusted taxable income (which resembles earnings before interest, taxes, depreciation and amortization).The regulations provide an annual safe harbor test that if at least 90 percent of consolidated plant assets consist of utility property, the entire consolidated group will be treated as a regulated public utility, and all of the consolidated group’s interest expense will be currently tax deductible. For 2018, Con Edison met the 90 percent safe harbor test and its deduction for interest expense was not limited. For 2019, Con Edison did not meet the 90 percent safe harbor test, however, its deduction for interest expense was not limited as a percentage of adjusted taxable income. In 2020, the federal government issued final regulations under the TCJA. Under the CARES Act, the limit of the deductible interest expense as a percentage of adjusted taxable income increased from 30 percent to 50 percent and accordingly, all of Con Edison’s interest expense in 2020 will be tax deductible. Qualifying consolidated groups would not be entitled to the full expensing provisions in the TCJA noted above. The safe harbor rules do not apply to partnerships in which Con Edison and its subsidiaries are a partner.

Uncertain Tax Positions

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 167

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

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Balance at January 1,	$13	$6	$12	$2	$4	$5
Additions based on tax positions related to the current year	—	1	2	—	1	2
Additions based on tax positions of prior years	1	10	1	1	—	1
Reductions for tax positions of prior years	—	(2)	(2)	—	(1)	(1)
Reductions from expiration of statute of limitations	—	—	(4)	—	—	—
Settlements	—	(2)	(3)	—	(2)	(3)
Balance at December 31,	$14	$13	$6	$3	$2	$4

At December 31, 2020, the estimated liability for uncertain tax positions for Con Edison was $14 million ($3 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 $14 million ($13 million, net of federal taxes) with $3 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 year ended December 31, 2020, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At December 31, 2020 and 2019, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

Con Edison's federal tax return for 2019 remains under examination. State and local income tax returns remain open for examination in New York State for tax years 2010 through 2019, in New Jersey for tax years 2016 through 2019 and in New York City for tax years 2015 and 2019.

168 CON EDISON ANNUAL REPORT 2020

Note M – Revenue Recognition

The following table presents, for the years ended December 31, 2020 and 2019, revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source.

	2020				2019				2018
(Millions of Dollars)	Revenues from contracts with customers		Other revenues (a)	Total operating revenues	Revenues from contracts with customers		Other revenues (a)	Total operating revenues	Revenues from contracts with customers		Other revenues (a)	Total operating revenues
CECONY
Electric	$8,026		$77	$8,103	$7,913		$149	$8,062	$7,920		$51	$7,971
Gas	1,998		38	2,036	2,097		35	2,132	2,052		26	2,078
Steam	494		14	508	610		17	627	625		6	631
Total CECONY	$10,518		$129	$10,647	$10,620		$201	$10,821	$10,597		$83	$10,680
O&R
Electric	619		10	629	627		7	634	647		(5)	642
Gas	224		9	233	247		12	259	256		(7)	249
Total O&R	$843		$19	$862	$874		$19	$893	$903		$(12)	$891
Clean Energy Businesses
Renewables	609	(b)	—	609	575	(b)	—	575	329	(b)	—	329
Energy services	52		—	52	71		—	71	95		—	95
Other	—		75	75	—		211	211	—		339	339
Total Clean Energy Businesses	$661		$75	$736	$646		$211	$857	$424		$339	$763
Con Edison Transmission	4		—	4	4		—	4	4		—	4
Other (c)	—		(3)	(3)	—		(1)	(1)	—		(1)	(1)
Total Con Edison	$12,026		$220	$12,246	$12,144		$430	$12,574	$11,928		$409	$12,337

(a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans. For the Clean Energy Businesses, this includes revenue from wholesale services.

(b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $8 million, $14 million and $103 million for the years ended December 31, 2020, 2019 and 2018, respectively, of revenue related to engineering, procurement and construction services.

(c) Parent company and consolidation adjustments.

Revenues are recorded as energy is delivered, generated or services are provided and billed to customers, except for services under percentage-of-completion contracts. Amounts billed are recorded in accounts receivable - customers, with payment generally due the following month. Con Edison’s and the Utilities’ accounts receivable - customers balance also reflects the Utilities’ purchase of receivables from energy service companies to support retail choice programs. Accrued revenues not yet billed to customers are recorded as accrued unbilled revenues.

The Utilities have the obligation to deliver electricity, gas and steam energy to their customers. As the energy is immediately available for use upon delivery to the customer, the energy and its delivery are identifiable as a single performance obligation. The Utilities recognize revenues as this performance obligation is satisfied over time as the Utilities deliver, and the customers simultaneously receive and consume, the energy. The amount of revenues recognized reflects the consideration the Utilities expect to receive in exchange for delivering the energy. Under their tariffs, the transaction price for full-service customers includes the Utilities’ energy cost and for all customers includes delivery charges determined based on customer class and in accordance with established tariffs and guidelines of the NYSPSC or the NJBPU, as applicable. Accordingly, there is no unsatisfied performance obligation associated with these customers. The transaction price is applied to the Utilities’ revenue generating activities through the customer billing process. Because energy is delivered over time, the Utilities use output methods that recognize revenue based on direct measurement of the value transferred, such as units delivered, which provides an accurate measure of value for the energy delivered. The Utilities accrue revenues at the end of each month for estimated energy delivered but not yet billed to customers. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 169

The Clean Energy Businesses recognize revenue for the sale of energy from renewable electric production projects as energy is generated and billed to counterparties; accrue revenues at the end of each month for energy generated but not yet billed to counterparties; and recognize revenue as energy is delivered and services are provided for managing energy supply assets leased from others and managing the dispatch, fuel requirements and risk management activities for generating plants and merchant transmission in the northeastern United States. The Clean Energy Businesses also recognize revenue for providing energy-efficiency services to government and commercial customers, and recognize revenue for engineering, procurement and construction services, under the percentage-of-completion method of revenue recognition.

Sales and profits on each percentage-of-completion contract are recorded each month based on the ratio of actual cumulative costs incurred to the total estimated costs at completion of the contract, multiplied by the total estimated contract revenue, less cumulative revenues recognized in prior periods (the ‘‘cost-to-cost’’ method). The impact of revisions of contract estimates, which may result from contract modifications, performance or other reasons, are recognized on a cumulative catch-up basis in the period in which the revisions are made.

	2020			2019			2018
(Millions of Dollars)	Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)
Beginning balance as of January 1,	$29	$17		$29	$20		$58	$87
Additions (c)	88	31		86	1		144	38
Subtractions (c)	106	7	(d)	86	4	(d)	173	105	(d)
Ending balance as of December 31,	$11	$41		$29	$17		$29	$20

(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, $7 million, $4 million and $50 million were included in the balances as of January 1, 2020, 2019, and 2018, respectively.

As of December 31, 2020, the aggregate amount of the remaining fixed performance obligations of the Clean Energy Businesses under contracts with customers for energy services is $216 million, of which $181 million will be recognized within the next two years, and the remaining $35 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.

The estimated amount of these foregone revenues for the year ended December 31, 2020 was $64 million and $61 million for Con Edison and CECONY, 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. See "COVID-19 Regulatory Matters" in Note B.

170 CON EDISON ANNUAL REPORT 2020

Note N – Stock-Based Compensation

The Companies may compensate employees and directors with, among other things, stock options, stock units, restricted stock units and contributions to the stock purchase plan. The Long Term Incentive Plan, which was approved by Con Edison’s shareholders in 2003 (2003 LTIP), and the Long Term Incentive Plan, which was approved by Con Edison’s shareholders in 2013 (2013 LTIP), are collectively referred to herein as the LTIP. The LTIP provides for, among other things, awards to employees of restricted stock units and stock options and, to Con Edison’s non-employee directors, stock units. Existing awards under the 2003 LTIP continue in effect, however no new awards may be issued under the 2003 LTIP. The 2013 LTIP provides for awards for up to five million shares of common stock.

Shares of Con Edison common stock used to satisfy the Companies’ obligations with respect to stock-based compensation may be new shares (authorized, but unissued) or treasury shares (existing treasury shares or shares purchased in the open market). The shares used during the year ended December 31, 2020 were new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2021.

The Companies recognized stock-based compensation expense using a fair value measurement method. The following table summarizes stock-based compensation expense recognized by the Companies in the years ended December 31, 2020, 2019 and 2018:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Performance-based restricted stock	$7	$36	$3	$6	$30	$3
Time-based restricted stock	1	2	2	1	2	1
Non-employee director deferred stock compensation	2	2	3	2	2	3
Stock purchase plan	7	7	6	7	6	6
Total	$17	$47	$14	$16	$40	$13
Income tax benefit	$5	$13	$4	$4	$11	$4

Restricted Stock and Stock Units

Restricted stock and stock unit awards under the LTIP have been made as follows: (i) awards that provide for adjustment of the number of units (performance-restricted stock units or Performance RSUs) to certain officers and employees; (ii) time-based awards to certain employees; and (iii) awards to non-employee directors. Restricted stock and stock units awarded represent the right to receive, upon vesting, shares of Con Edison common stock, or, except for units awarded under the directors’ plan, the cash value of shares or a combination thereof.

The number of units in each annual Performance RSU award is subject to adjustment as follows: (i) 50 percent of the units awarded will be multiplied by a factor that may range from 0 to 200 percent, based on Con Edison’s total shareholder return relative to a specified peer group during a specified performance period (the TSR portion); and (ii) 50 percent of the units awarded will be multiplied by factors that may range from 0 to 200 percent, based on determinations made in connection with the Companies’ annual incentive plans or, for certain executive officers, actual performance as compared to certain performance measures during a specified performance period (the non-TSR portion). Performance RSU awards generally vest upon completion of the performance period.

Performance against the established targets is recomputed each reporting period as of the earlier of the reporting date and the vesting date. The TSR portion applies a Monte Carlo simulation model, and the non-TSR portion is the product of the market price at the end of the period and the average non-TSR determination over the vesting period. Performance RSUs are “liability awards” because each Performance RSU represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, changes in the fair value of the Performance RSUs are reflected in net income. The assumptions used to calculate the fair value of the awards were as follows:

	2020	2019	2018
Risk-free interest rate (a)	0.10% - 0.13%	1.58% - 1.59%	2.48% -2.63%
Expected term (b)	3 years	3 years	3 years
Expected share price volatility (c)	30.16% - 40.95%	12.89% - 15.51%	14.76% - 17.71%

(a)The risk-free rate is based on the U.S. Treasury zero-coupon yield curve.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 171

(b)The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur.

(c)Based on historical experience.

A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2020 is as follows:

	Con Edison			CECONY
		Weighted Average Grant Date Fair Value (a)			Weighted Average Grant Date Fair Value (a)
	Units	TSR Portion (b)	Non-TSR Portion (c)	Units	TSR Portion (b)	Non-TSR Portion (c)
Non-vested at December 31, 2019	991,238	$68.15	$77.14	742,204	$68.06	$77.32
Granted	329,600	79.98	90.48	249,761	79.70	89.65
Vested	(326,496)	73.07	74.57	(245,269)	72.70	74.76
Forfeited	(92,818)	73.80	87.98	(60,225)	73.61	87.73
Non-vested at December 31, 2020	901,524	$70.11	$81.83	686,471	$70.15	$81.80

(a)The TSR and non-TSR Portions each account for 50 percent of the awards’ value.

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

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

The total expense to be recognized by Con Edison in future periods for unvested Performance RSUs outstanding at December 31, 2020 is $21 million, including $17 million for CECONY, and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY. Con Edison and CECONY paid cash of $21 million and $18 million in 2020, $24 million and $22 million in 2019, and $29 million and $28 million in 2018, respectively, to settle vested Performance RSUs.

In accordance with the accounting rules for stock compensation, for time-based awards, the Companies are accruing a liability and recognizing compensation expense based on the market value of a common share throughout the vesting period. The vesting period for awards is three years and is based on the employee’s continuous service to Con Edison. Prior to vesting, the awards are subject to forfeiture in whole or in part under certain circumstances. The awards are “liability awards” because each restricted stock unit represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, prior to vesting, changes in the fair value of the units are reflected in net income.

A summary of changes in the status of time-based awards during the year ended December 31, 2020 is as follows:

	Con Edison		CECONY
	Units	Weighted Average Grant Date Fair Value	Units	Weighted Average Grant Date Fair Value
Non-vested at December 31, 2019	67,250	$80.36	63,100	$80.36
Granted	22,450	78.00	20,900	78.00
Vested	(20,750)	77.66	(19,650)	77.66
Forfeited	(1,512)	80.30	(1,512)	80.30
Non-vested at December 31, 2020	67,438	$80.40	62,838	$80.42

The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2020 for Con Edison and CECONY was $2 million and is expected to be recognized over a weighted average period of one year. Con Edison and CECONY paid cash of $1 million in 2020, 2019 and 2018, to settle vested time-based awards.

Under the LTIP, each non-employee director receives stock units, which are deferred until the director’s separation from service or another date specified by the director. Each director may also elect to defer all or a portion of their cash compensation into additional stock units, which are deferred until the director’s termination of service or another date specified by the director. Non-employee directors’ stock units issued under the LTIP are considered “equity awards,” because they may only be settled in shares. Directors immediately vest in units issued to them.

172 CON EDISON ANNUAL REPORT 2020

The fair value of the units is determined using the closing price of Con Edison’s common stock on the business day immediately preceding the date of issue. In the year ended December 31, 2020, approximately 33,200 units were issued at a weighted average grant date price of $74.32.

Stock Purchase Plan

The Stock Purchase Plan, which was approved by shareholders in 2004 and 2014, provides for the Companies to contribute up to $1 for each $9 invested by their directors, officers or employees to purchase Con Edison common stock under the plan. Eligible participants may invest up to $25,000 during any calendar year (subject to an additional limitation for officers and employees of not more than 20 percent of their pay). Dividends paid on shares held under the plan are reinvested in additional shares unless otherwise directed by the participant.

Participants in the plan immediately vest in shares purchased by them under the plan. Prior to September 1, 2020, the fair value of the shares of Con Edison common stock purchased under the plan was calculated using the average of the high and low composite sale prices at which shares were traded at the New York Stock Exchange on the trading day immediately preceding such purchase dates. During 2020, the plan was amended and as a result of the amendment, the fair value of the shares of Con Edison common stock purchased after September 1, 2020 under the plan was calculated using the closing price at which shares were traded on the New York Stock Exchange on the last business day of the month for all shares purchased during the month. During 2020, 2019 and 2018, 836,984, 747,899 and 786,385 shares were purchased under the Stock Purchase Plan at a weighted average price of $79.82, $85.45 and $78.27 per share, respectively.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 173

Note O – Financial Information by Business Segment

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

Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities.

All revenues of these business segments are from customers located in the United States of America. Also, all assets of the business segments are located in the United States of America. The accounting policies of the segments are the same as those described in Note A.

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

The financial data for the business segments are as follows:

As of and for the Year Ended December 31, 2020 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$8,103	$18	$1,214	$1,731	$(134)	$535	$130	$35,673	$2,080
Gas	2,036	7	294	574	(25)	164	102	12,678	1,044
Steam	508	74	90	5	(12)	40	(14)	2,616	122
Consolidation adjustments	—	(99)	—	—	—	—	—	—	—
Total CECONY	$10,647	$—	$1,598	$2,310	($171)	$739	$218	$50,967	$3,246
O&R
Electric	$629	$—	$65	$99	$(10)	$26	$13	$2,097	$159
Gas	233	—	25	48	(4)	15	8	1,150	61
Other	—	—	—	—	—	—	—	—	—
Total O&R	$862	$—	$90	$147	$(14)	$41	$21	$3,247	$220
Clean Energy Businesses	$736	$—	$231	$215	$4	$196	$(43)	$6,848	$616
Con Edison Transmission	4	—	1	(8)	(215)	18	—	1,348	3
Other (b)	(3)	—	—	(10)	(5)	25	(3)	485	—
Total Con Edison	$12,246	$—	$1,920	$2,654	$(401)	$1,019	$193	$62,895	$4,085

As of and for the Year Ended December 31, 2019 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$8,062	$17	$1,053	$1,758	$(28)	$539	$239	$32,988	$1,851
Gas	2,132	7	231	528	(4)	147	99	11,090	1,078
Steam	627	70	89	62	(3)	42	4	2,479	91
Consolidation adjustments	—	(94)	—	—	—	—	—	—	—
Total CECONY	$10,821	$—	$1,373	$2,348	$(35)	$728	$342	$46,557	$3,020
O&R
Electric	$634	$—	$60	$98	$(7)	$27	$15	$2,130	$142
Gas	259	—	24	41	(4)	14	6	876	61
Other	—	—	—	—	—	—	—	—	—
Total O&R	$893	$—	$84	$139	$(11)	$41	$21	$3,006	$203
Clean Energy Businesses	$857	$—	$226	$202	$5	$186	$(58)	$6,528	$248
Con Edison Transmission	4	—	1	(6)	104	25	1	1,618	205
Other (b)	(1)	—	—	(7)	(12)	11	(6)	370	—
Total Con Edison	$12,574	$—	$1,684	$2,676	$51	$991	$300	$58,079	$3,676

174 CON EDISON ANNUAL REPORT 2020

As of and for the Year Ended December 31, 2018 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$7,971	$16	$984	$1,799	$(110)	$519	$233	$31,012	$1,861
Gas	2,078	7	205	478	(23)	131	87	9,710	1,050
Steam	631	75	87	77	(10)	39	8	2,386	94
Consolidation adjustments	—	(98)	—	—	—	—	—	—	—
Total CECONY	$10,680	$—	$1,276	$2,354	$(143)	$689	$328	$43,108	$3,005
O&R
Electric	$642	$—	$56	$93	$(14)	$25	$14	$2,036	$138
Gas	249	—	21	39	(5)	14	7	856	67
Other	—	—	—	—	—	—	—	—	—
Total O&R	$891	$—	$77	$132	$(19)	$39	$21	$2,892	$205
Clean Energy Businesses	$763	$—	$85	$194	$33	$63	$19	$5,821	$1,791
Con Edison Transmission	4	—	1	(7)	91	20	(1)	1,425	248
Other (b)	(1)	—	(1)	(9)	(24)	8	39	674	—
Total Con Edison	$12,337	$—	$1,438	$2,664	$(62)	$819	$406	$53,920	$5,249

(a)For Con Edison, the income tax expense/(benefit) on non-operating income was $(103) million, $(4) million and $(5) million in 2020, 2019 and 2018, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(3) million, $(7) million and $(2) million in 2020, 2019 and 2018, respectively.

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 175

Note P – 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 Q), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules.

In August 2017, the FASB issued amendments to the guidance for derivatives and hedging through ASU 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities.” The amendments in this update provide greater clarification on hedge accounting for risk components, presentation and disclosure of hedging instruments, and overall targeted improvements to simplify hedge accounting. The amendments were effective for reporting periods beginning after December 15, 2018. The application of the guidance did not have a material impact on the Companies’ financial position, results of operations and liquidity because the Companies do not elect hedge accounting for their derivative instruments and hedging activities.

The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2020 and 2019 were:

(Millions of Dollars)	2020				2019
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	$44	$14	$58	(b)	$60	$(3)	$57	(b)
Noncurrent	22	35	57		19	(13)	6	(d)
Total fair value of derivative assets	$66	$49	$115		$79	$(16)	$63
Fair value of derivative liabilities
Current	$(225)	$(13)	$(238)	(c)	$(140)	$17	$(123)	(d)
Noncurrent	(207)	(33)	(240)	(c)	(122)	16	(106)	(d)
Total fair value of derivative liabilities	$(432)	$(46)	$(478)		$(262)	$33	$(229)
Net fair value derivative assets/(liabilities)	$(366)	$3	$(363)		$(183)	$17	$(166)
CECONY
Fair value of derivative assets
Current	$20	$(12)	$8	(b)	$39	$(6)	$33	(b)
Noncurrent	16	(8)	8		17	(12)	5
Total fair value of derivative assets	$36	$(20)	$16		$56	$(18)	$38
Fair value of derivative liabilities
Current	$(174)	$11	$(163)		$(100)	$19	$(81)
Noncurrent	(114)	9	(105)		(80)	16	(64)
Total fair value of derivative liabilities	$(288)	$20	$(268)		$(180)	$35	$(145)
Net fair value derivative assets/(liabilities)	$(252)	$—	$(252)		$(124)	$17	$(107)

 

(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 December 31, 2020 and 2019, margin deposits for Con Edison ($3 million and $9 million, respectively) and CECONY ($3 million and $8 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

176 CON EDISON ANNUAL REPORT 2020

(c)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 range from 2024-2041.

(d)Includes amounts for interest rate swaps of $1 million in current assets, $(7) million in current liabilities and $(34) million in noncurrent liabilities. At December 31, 2019, the Clean Energy Businesses had interest rate swaps with notional amounts of $919 million. The expiration dates of the swaps range 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. See "Recoverable Energy Costs" in Note A. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements.

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 years ended December 31, 2020 and 2019:

		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2020	2019	2020	2019
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(26)	$4	$(27)	$5
Noncurrent	Deferred derivative gains	—	(3)	—	(1)
Total deferred gains/(losses)		$(26)	$1	$(27)	$4
Current	Deferred derivative losses	$(63)	$(91)	$(64)	$(83)
Current	Recoverable energy costs	(201)	(142)	(177)	(124)
Noncurrent	Deferred derivative losses	(37)	(67)	(36)	(65)
Total deferred gains/(losses)		$(301)	$(300)	$(277)	$(272)
Net deferred gains/(losses)		$(327)	$(299)	$(304)	$(268)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Gas purchased for resale	$(2)	$(2)	$—	$—
	Non-utility revenue	7	25	—	—
	Other operations and maintenance expense	(3)	1	(3)	1
	Other interest expense	(65)	(36)	—	—
Total pre-tax gain/(loss) recognized in income		$(63)	$(12)	$(3)	$1

 

The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2020:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	28,102,230	47,258	286,819,910	7,728,000
CECONY	26,193,800	35,400	267,380,000	7,728,000

 

(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,

                                                                                                                         CON EDISON ANNUAL REPORT 2020 177

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 December 31, 2020, Con Edison and CECONY had $217 million and $16 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 $103 million with independent system operators, $47 million with investment-grade counterparties, $40 million with non-investment grade/non-rated counterparties, and $27 million with commodity exchange brokers. CECONY’s net credit exposure consisted of $16 million with commodity exchange brokers.

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 December 31, 2020:

(Millions of Dollars)	Con Edison (a)	CECONY (a)
Aggregate fair value – net liabilities	$293	$277
Collateral posted	212	200
Additional collateral (b) (downgrade one level from current ratings)	5	—
Additional collateral (b)(c) (downgrade to below investment grade from current ratings)	101	85

 

(a)Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $25 million at December 31, 2020. 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 December 31, 2020, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $51 million.

Note Q – 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:

178 CON EDISON ANNUAL REPORT 2020

•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.

For information on the measurement of Con Edison's investment in MVP, which was measured at fair value on a non-recurring basis, see Note A. Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2020 and 2019 are summarized below.

	2020					2019
(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)	$19	$42	$4	$53	$118	$4	$61	$2	$4	$71
Interest rate swaps (a)(b)(c)(f)	—	—	—	—	—	—	1	—	—	1
Other (a)(b)(d)	431	126	—	—	557	353	125	—	—	478
Total assets	$450	$168	$4	$53	$675	$357	$187	$2	$4	$550
Derivative liabilities:
Commodity (a)(b)(c)	$7	$296	$23	$46	$372	$18	$174	$18	$(22)	$188
Interest rate swaps (a)(b)(c)(f)	—	106	—	—	106	—	41	—	—	41
Total liabilities	$7	$402	$23	$46	$478	$18	$215	$18	$(22)	$229
CECONY
Derivative assets:
Commodity (a)(b)(c)	$15	$20	$—	$(16)	$19	$3	$42	$1	$—	$46
Other (a)(b)(d)	411	120	—	—	531	333	119	—	—	452
Total assets	$426	$140	$—	$(16)	$550	$336	$161	$1	$—	$498
Derivative liabilities:
Commodity (a)(b)(c)	$3	$274	$10	$(19)	$268	$15	$147	$7	$(24)	$145

 

(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 $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. Con Edison and CECONY had $24 million and $22 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2019 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of December 31, 2017 to less than three years as of December 31, 2019.

(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 December 31, 2020 and 2019, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 179

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

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

(f)See Note P.

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 December 31, 2020
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison — Commodity
Electricity	(20)	Discounted Cash Flow	Forward capacity prices (a)	$0.06-$6.26 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(2.65)-$7.69 per MWh
Total Con Edison — Commodity	$(19)
CECONY — Commodity
Electricity	$(11)	Discounted Cash Flow	Forward capacity prices (a)	$0.08-$6.26 per kW-month
Transmission Congestion Contracts	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.23-$1.13 per MWh
Total CECONY — Commodity	$(10)

 

(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 for the years ended December 31, 2020 and 2019 and classified as Level 3 in the fair value hierarchy:

 

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Beginning balance as of January 1,	$(16)	$(13)	$(6)	$(2)
Included in earnings	(10)	(5)	(5)	—
Included in regulatory assets and liabilities	(7)	18	(4)	17
Settlements	15	8	6	1
Transfer out of level 3	(1)	(24)	(1)	(22)
Ending balance as of December 31,	$(19)	$(16)	$(10)	$(6)

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. See Note A. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations.

For the Clean Energy Businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($3 million gain and $2 million gain) on the consolidated income statement for the years ended December 31, 2020 and 2019, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at December 31, 2020 and 2019 is included in non-utility revenues ($2 million gain) on the consolidated income statement for the years ended December 31, 2020 and 2019.

180 CON EDISON ANNUAL REPORT 2020

Note R – 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. In April 2017, CECONY's long-term electricity purchase agreement with Cogen Technologies Linden Venture, LP (Linden Cogeneration), another potential VIE, expired. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY's maximum exposure to loss with respect to the potential VIEs.

Clean Energy Businesses

In September 2019, the Clean Energy Businesses, which previously owned an 80 percent membership interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), acquired the remaining 20 percent interest. As a result of the acquisition, Texas Solar 4 is a consolidated entity. Prior to the acquisition, Con Edison had a variable interest in Texas Solar 4, as to which Con Edison was the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 was held by the Clean Energy Businesses. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project. Electricity generated by the project is sold pursuant to a long-term power purchase agreement. Con Edison's earnings from Texas Solar 4 for the years ended December 31, 2019 and 2018 were immaterial.

In December 2018, the Clean Energy Businesses completed its acquisition of Sempra Solar Holdings, LLC. See Note V. 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 year ended December 31, 2020, the hypothetical liquidation at book value (HLBV) method of accounting for the Tax Equity Projects resulted in $44 million of income ($32 million, after tax) for the tax equity investor and a $6 million loss ($4 million, after tax) for Con Edison. For the year ended December 31, 2019, the HLBV method of accounting for the Tax Equity Projects resulted in $98 million of income ($74 million, after tax) for the tax equity investor and a $64 million loss ($48 million, after tax) for Con Edison, and earnings under the HLBV method for the year ended December 31, 2018 were immaterial.

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.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 181

At December 31, 2020 and 2019, 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)
(Millions of Dollars)	2020	2019	2020	2019
Non-utility property, less accumulated depreciation (f)(g)	284	293	446	461
Other assets	39	40	176	128
Total assets (a)	$323	$333	$622	$589
Other liabilities	13	17	71	18
Total liabilities (b)	$13	$17	$71	$18

(a)The assets of the Tax Equity Projects 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 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 $82 million and $62 million at December 31, 2020 and 2019, 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 $134 million and $126 million at December 31, 2020 and 2019, respectively.

(f)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.

(g)Non-utility property is reduced by accumulated depreciation of $9 million for Great Valley Solar, $15 million for Copper Mountain - Mesquite Solar at December 31, 2019.

The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2020:

Project Name	Generating Capacity (a) (MW AC)	Power Purchase Agreement Term in Years	Year of Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (b)
Great Valley Solar (c)	200	15-20	2018	California	$228
Copper Mountain - Mesquite Solar (c)	344	20-25	2018	Nevada and Arizona	417

 

(a)Represents ownership interest in the project.

(b)Maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

(c)For the projects comprising Great Valley Solar and Copper Mountain Mesquite Solar, refer to (d) and (e) in the table above.

Note S – Asset Retirement Obligations

The Companies recognize a liability at fair value for legal obligations associated with the retirement of long-lived assets in the period in which they are incurred, or when sufficient information becomes available to reasonably estimate the fair value of such legal obligations. When the liability is initially recorded, asset retirement costs are capitalized by increasing the carrying amount of the related asset. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. The fair value of the asset retirement obligation liability is measured using expected future cash flows discounted at credit-adjusted risk-free rates, historical information, and where available, quoted prices from outside contractors. The Companies evaluate these assumptions underlying the asset retirement obligation liability on an annual basis or as frequently as needed.

The Companies recorded asset retirement obligations associated with the removal of asbestos and asbestos-containing material in their buildings (other than the structures enclosing generating stations and substations), electric equipment and steam and gas distribution systems. The Companies also recorded asset retirement obligations relating to gas and oil pipelines abandoned in place and municipal infrastructure support.

The Companies did not record an asset retirement obligation for the removal of asbestos associated with the structures enclosing generating stations and substations. For these building structures, the Companies were unable

182 CON EDISON ANNUAL REPORT 2020

to reasonably estimate their asset retirement obligations because the Companies were unable to estimate the undiscounted retirement costs or the retirement dates and settlement dates. The amount of the undiscounted retirement costs could vary considerably depending on the disposition method for the building structures, and the method has not been determined. The Companies anticipate continuing to use these building structures in their businesses for an indefinite period, and so the retirement dates and settlement dates are not determinable.

Con Edison recorded asset retirement obligations for the removal of the Clean Energy Businesses’ solar and wind equipment related to projects located on property that is not owned by them and the term of the arrangement is finite including any renewal options. Con Edison did not record asset retirement obligations for the Clean Energy Businesses’ projects that are located on property that is owned by them because they expect that the equipment will continue to generate electricity at these facilities long past the manufacturer’s warranty at minimal operating expense. Therefore, Con Edison was unable to reasonably estimate the retirement date of this equipment.

The Utilities include in depreciation rates the estimated removal costs, less salvage, for utility plant assets. The amounts related to removal costs that are associated with asset retirement obligations are classified as an asset retirement liability. Pursuant to accounting rules for regulated operations, future removal costs that do not represent legal asset retirement obligations are recorded as regulatory liabilities. Accretion and depreciation expenses related to removal costs that represent legal asset retirement obligations are applied against the Companies’ regulatory liabilities. Asset retirement costs that are recoverable from customers are recorded as regulatory liabilities to reflect the timing difference between costs recovered through the rate-making process and recognition of costs.

At December 31, 2020, the liabilities for asset retirement obligations of Con Edison and CECONY were $576 million and $508 million, respectively. At December 31, 2019, the liabilities for asset retirement obligations of Con Edison and CECONY were $425 million and $362 million, respectively. The change in liabilities at December 31, 2020 was due to changes in estimated cash flows of $191 million and $186 million for Con Edison and CECONY, respectively, and accretion expense of $16 million and $13 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $56 million and $53 million for Con Edison and CECONY, respectively. The change in liabilities at December 31, 2019 was due to changes in estimated cash flows of $(1) million and $96 million for Con Edison and CECONY, respectively, and accretion expense of $14 million and $12 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $38 million for both Con Edison and CECONY. Con Edison and CECONY also recorded reductions of $49 million and $44 million during the years ended December 31, 2020 and 2019, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.

Note T – Related Party Transactions

The NYSPSC generally requires that the Utilities and Con Edison’s other subsidiaries be operated as separate entities. The Utilities and the other subsidiaries are required to have separate operating employees and operating officers of the Utilities may not be operating officers of the other subsidiaries. The Utilities may provide administrative and other services to, and receive such services from, Con Edison and its other subsidiaries only pursuant to cost allocation procedures approved by the NYSPSC. Transfers of assets between the Utilities and Con Edison or its other subsidiaries may be made only as approved by the NYSPSC. The debt of the Utilities is to be raised directly by the Utilities and not derived from Con Edison. Without the prior permission of the NYSPSC, the Utilities may not make loans to, guarantee the obligations of, or pledge assets as security for the indebtedness of Con Edison or its other subsidiaries. The NYSPSC limits the dividends that the Utilities may pay Con Edison. See “Dividends” in Note C. As a result, substantially all of the net assets of CECONY and O&R ($14,849 million and $807 million, respectively), at December 31, 2020, are considered restricted net assets. The NYSPSC may impose additional measures to separate, or “ring fence,” the Utilities from Con Edison and its other subsidiaries. See “Rate Plans” in Note B.

The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2020, 2019 and 2018 were as follows:

	CECONY
(Millions of Dollars)	2020	2019	2018
Cost of services provided	$128	$121	$115
Cost of services received	66	64	73

                                                                                                                         CON EDISON ANNUAL REPORT 2020 183

In addition, CECONY and O&R have joint gas supply arrangements in connection with which CECONY sold to O&R $59 million, $71 million and $83 million of natural gas for the years ended December 31, 2020, 2019 and 2018, respectively. These amounts are net of the effect of related hedging transactions.

The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric has a 45.7 percent equity interest. The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the years ended December 31, 2020 and 2019, the amounts billed by the Utilities to NY Transco were immaterial. In May 2016, CECONY transferred certain electric transmission projects to NY Transco.

CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC, (Stagecoach), a joint venture formed by a subsidiary of CET Gas and a subsidiary of Crestwood Equity Partners LP (Crestwood). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. CECONY incurred costs for storage and wheeling services from Stagecoach of $34 million, $33 million and $28 million for the years ended December 31, 2020, 2019 and 2018, respectively.

CECONY has a 20-year transportation contract with Mountain Valley Pipeline, LLC (MVP) for 250,000 dekatherms per day of capacity. CET Gas owns an 11.3 percent equity interest in MVP (that is expected to be reduced to 8.8 percent). See "Investments" in Note A. In October 2017, the Environmental Defense Fund and the Natural Resource Defense Council requested the NYSPSC to prohibit CECONY from recovering costs under its MVP contract unless CECONY can demonstrate that the contract is in the public interest. CECONY advised the NYSPSC that it would respond to the request if the NYSPSC opened a proceeding to consider this request. For the years ended December 31, 2020 and 2019, CECONY incurred no costs under the contract.

FERC has authorized CECONY to lend funds to O&R for a period of not more than 12 months, in an amount not to exceed $250 million, at prevailing market rates. At December 31, 2020 and 2019 there were no outstanding loans to O&R.

The Clean Energy Businesses had financial electric capacity contracts with CECONY and O&R during 2020 and 2019. For the years ended December 31, 2020 and 2019, the Clean Energy Businesses realized an immaterial loss and a $1 million loss, respectively, under these contracts.

Note U – New Financial Accounting Standards

In December 2019, the FASB issued amendments to the guidance for income taxes through ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” The amendments in this update simplify the accounting for income taxes by removing certain exceptions such as: 1) the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, 2) the requirement to recognize a deferred tax liability for equity method investments when a foreign subsidiary becomes an equity method investment, 3) the ability not to recognize a deferred tax liability for a foreign subsidiary when a foreign equity method investment becomes a subsidiary, and 4) the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. For public entities, the amendments are effective for reporting periods beginning after December 15, 2020. Early adoption is permitted. The application of this guidance will not have a material impact on the Companies’ financial position, results of operations and liquidity.

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 November 2020, LIBOR’s administrator announced it plans to consult on its intention to cease publication of one-week and two-month U.S. Dollar LIBOR immediately after the LIBOR publication on December 31, 2021, and the remaining U.S. Dollar LIBOR tenors immediately after publication on June 30, 2023. 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

184 CON EDISON ANNUAL REPORT 2020

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 from any date beginning March 12, 2020. 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 V – Acquisitions and Investments

Sempra Solar

In December 2018, the Clean Energy Businesses completed their acquisition of Sempra Solar Holdings, LLC, a Sempra Energy subsidiary, for $1,609 million, including working capital and other closing adjustments of $69 million. In 2019, Con Edison finalized the purchase price allocation and reclassified approximately $100 million which primarily decreased property, plant and equipment and asset retirement obligations, the impact of which was not material to earnings. The reclassification was recorded within the one year available to finalize the purchase price allocation.

The acquired company has ownership interests in 981 megawatts (AC) of operating renewable electric production projects, including its 379 megawatts (AC) share of projects in which its subsidiaries had a 50 percent ownership interest (Acquired JV Interests) and the Clean Energy Businesses had the remaining ownership interests (Previously-Owned JV Interests), and certain development rights with respect to solar electric production and energy storage projects.

At the acquisition date, the acquired company’s subsidiaries had $1,354 million of tangible assets consisting mostly of property, plant and equipment, $878 million of intangible assets mostly arising from power purchase agreements, $4 million of other noncurrent assets, $568 million of project debt (including, in each case, amounts associated with the Acquired JV Interests) and $28 million of asset retirement obligation liabilities. The weighted average amortization period for these intangible assets is 16 years. At the acquisition date, the fair value of the noncontrolling interest attributable to the tax equity investors (see below) was $100 million. The acquisition date valuation was performed using a discounted cash flow approach. The fair values of assets acquired and liabilities assumed were determined based on significant estimates and assumptions that are judgmental in nature, including projected amounts and timing of future cash flows, discount rates reflecting risk inherent in the future cash flows and future power prices.

Upon completion of the acquisition, the acquisition date fair value of the Previously-Owned JV Interests increased from $437 million to $568 million and Con Edison recognized a pre-tax gain of $131 million ($89 million or $0.28 per share net of taxes). Prior to the acquisition, Con Edison had been accounting for the Previously-Owned JV Interests under the equity method. Upon completion of the acquisition, Con Edison is accounting for Acquired JV Interests and the Previously-Owned JV Interests on a consolidated basis.

Certain projects acquired have tax equity investors to which a percentage of earnings, tax attributes and cash flows are allocated. See Note R.

Con Edison's revenues and net income for the years ended December 31, 2018 and 2017 as reported and pro forma to account on a consolidated basis for the acquisition as if the acquisition had been completed on January 1, 2017 instead of December 13, 2018 are as follows:

	Years ended December 31,
(Millions of Dollars)	2018	2017
As Reported
Revenue	$12,337	$12,033
Net income	1,382	1,525
PRO FORMA SUPPLEMENTAL INFORMATION
If Acquired January 1, 2017 (a)(b)
Revenue	$12,655	$12,331
Net income	1,279	1,612

(a) Reflects the following material adjustments:

                                                                                                                         CON EDISON ANNUAL REPORT 2020 185

•included additional interest expense of $37 million and $38 million in 2018 and 2017, respectively, that would have been incurred if $825 million that was borrowed in December 2018 under a variable rate term loan agreement to fund a portion of the purchase price for the acquisition had instead been borrowed for such purpose on January 1, 2017 at a fixed rate of 4.64% per annum; and

•with respect to the Previously-Owned JV Interests: eliminated the $131 million purchase accounting gain (pre-tax) that Con Edison recognized upon the completion of the acquisition in 2018 and reflected the $131 million purchase accounting gain in 2017; recorded the corresponding increase to the book value of the related net utility plant and power purchase agreement intangible asset as of January 1, 2017 instead of December 13, 2018, and included the increased depreciation and amortization expense in 2018 and 2017; and eliminated $33 million and $32 million of other income that Con Edison had recorded in 2018 and 2017, respectively, under the equity method of accounting.

(b) Recalculating each investor’s claim on the investee’s assets under the contractual liquidation waterfall as if the acquisition had been completed on January 1, 2017 is impracticable. Accordingly, no HLBV adjustments were made.

186 CON EDISON ANNUAL REPORT 2020

Schedule I

Condensed Financial Information of Consolidated Edison, Inc. (a)

Condensed Statement of Income and Comprehensive Income

(Parent Company Only)

	For the Years Ended December 31,
(Millions of Dollars, except per share amounts)	2020	2019	2018
Equity in earnings of subsidiaries	$1,105	$1,354	$1,447
Other income (deductions), net of taxes	56	76	(6)
Interest expense	(60)	(87)	(59)
Net Income	$1,101	$1,343	$1,382
Comprehensive Income	$1,095	$1,340	$1,392
Net Income Per Share – Basic	$3.29	$4.09	$4.43
Net Income Per Share – Diluted	$3.28	$4.08	$4.42
Dividends Declared Per Share	$3.06	$2.96	$2.86
Average Number Of Shares Outstanding—Basic (In Millions)	334.8	328.5	311.1
Average Number Of Shares Outstanding—Diluted (In Millions)	335.7	329.5	312.9

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 187

Condensed Financial Information of Consolidated Edison, Inc. (a)

Condensed Statement of Cash Flows

(Parent Company Only)

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Net Income	1,101	1,343	1,382
Equity in earnings of subsidiaries	(1,105)	(1,354)	(1,447)
Dividends received from:
CECONY	982	912	846
O&R	49	47	46
Clean Energy Businesses	21	3	15
Con Edison Transmission	11	12	10
Change in Assets:
Special deposits	—	(3)	(8)
Income taxes receivable	—	25	2
Other – net	654	44	187
Net Cash Flows from Operating Activities	1,713	1,029	1,033
Investing Activities
Contributions to subsidiaries	(626)	(930)	(1,110)
Debt receivable from affiliated companies	400	450	(825)
Net Cash Flows Used in Investing Activities	(226)	(480)	(1,935)
Financing Activities
Net proceeds of short-term debt	(537)	(783)	164
Issuance of long-term debt	650	825	825
Retirement of long-term debt	(1,178)	(553)	(3)
Debt issuance costs	(3)	—	—
Issuance of common shares for stock plans, net of repurchases	58	54	53
Issuance of common shares - public offering	640	825	705
Common stock dividends	(975)	(924)	(842)
Net Cash Flows Used in Financing Activities	(1,345)	(556)	902
Net Change for the Period	142	(7)	—
Balance at Beginning of Period	2	9	9
Balance at End of Period	$144	$2	$9

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

188 CON EDISON ANNUAL REPORT 2020

Condensed Financial Information of Consolidated Edison, Inc. (a)

Condensed Balance Sheet

(Parent Company Only)

	December 31,
(Millions of Dollars)	2020	2019
Assets
Current Assets
Cash and temporary cash investments	$144	$2
Accounts receivable - other	1
Income taxes receivable	18	18
Term loan receivable from affiliated companies	—	—
Accounts receivable from affiliated companies	1,256	870
Prepayments	62	32
Other current assets	12	12
Total Current Assets	1,493	934
Investments in subsidiaries and others	18,670	18,009
Goodwill	406	406
Deferred income tax	55	14
Long-term debt receivable from affiliated companies	875	1,275
Other noncurrent assets	—	—
Total Assets	$21,499	$20,638
Liabilities and Shareholders’ Equity
Current Liabilities
Long-term debt due within one year	$1,178	$3
Term loan	—	—
Notes payable	—	537
Accounts payable	—	—
Accounts payable to affiliated companies	517	595
Accrued taxes	6	2
Other current liabilities	12	10
Total Current Liabilities	1,713	1,147
Deferred income tax	—	—
Total Liabilities	1,713	1,147
Long-term debt	939	1,469
Shareholders’ Equity
Common stock, including additional paid-in capital	8,844	8,089
Retained earnings	10,003	9,933
Total Shareholders’ Equity	18,847	18,022
Total Liabilities and Shareholders’ Equity	$21,499	$20,638

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

                                                                                                                         CON EDISON ANNUAL REPORT 2020 189

Schedule II

Valuation and Qualifying Accounts

For the Years Ended December 31, 2020, 2019 and 2018

				COLUMN C Additions
Company (Millions of Dollars)	COLUMN A Description		COLUMN B Balance at Beginning of Period	(1) Charged To Costs And Expenses	(2) Charged To Other Accounts	COLUMN D Deductions (b)	COLUMN E Balance At End of Period
Con Edison	Allowance for uncollectible accounts (a):
		2020	$74	$72	$—	$8	$154
		2019	$68	$77	$—	$(71)	$74
		2018	$70	$62	$—	$(64)	$68
CECONY	Allowance for uncollectible accounts (a):
		2020	$68	$65	$—	$10	$143
		2019	$61	$72	$—	$(65)	$68
		2018	$65	$56	$—	$(60)	$61

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

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

190 CON EDISON ANNUAL REPORT 2020

Item 9:    Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

Con Edison

None.

CECONY

None.

Item 9A: 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.

For the Companies’ Reports of Management On Internal Control Over Financial Reporting and the related opinions of PricewaterhouseCoopers LLP (presented in the Reports of Independent Registered Public Accounting Firm), see Item 8 of this report (which information is incorporated herein by reference).

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.

Item 9B: Other Information

Con Edison

None.

CECONY

None.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 191

Part III

Item 10: Directors, Executive Officers and Corporate Governance

Item 11: Executive Compensation

Item 12: Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

Item 13: Certain Relationships and Related Transactions, and Director Independence

Item 14: Principal Accounting Fees and Services

Con Edison

Information required by Part III as to Con Edison, other than the information required in Item 12 of this report by Item 201(d) of Regulation S-K, is incorporated by reference from Con Edison’s definitive proxy statement for its Annual Meeting of Stockholders to be held on May 17, 2021. The proxy statement is to be filed pursuant to Regulation 14A not later than 120 days after December 31, 2020, the close of the fiscal year covered by this report. 

The information required pursuant to Item 201(d) of Regulation S-K as at December 31, 2020 is as follows:

Equity Compensation Plan Information 

Plan category	Number of securities to be issued upon exercise of outstanding options, warrants and rights		Weighted-average exercise price of outstanding options, warrants and rights	Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (1))
	(1)		(2)	(3)
Equity compensation plans approved by security holders
2003 LTIP (a)	191,425		—	—
2013 LTIP (b)	1,316,301		—	4,171,080
Stock Purchase Plan (c)	—		—	4,975,678
Total equity compensation plans approved by security holders	1,507,726		—	9,146,758
Total equity compensation plans not approved by security holders	1,500	(d)	—	—
Total	1,509,226		—	9,146,758

(a)The number of shares of Con Edison common stock that may be issued pursuant to outstanding awards under the Long Term Incentive Plan approved by the company’s shareholders in 2003 (the “2003 LTIP”) include 191,425 shares for stock unit awards made prior to 2013 that have vested and for which the receipt of shares was deferred. Amounts do not include shares that may be issued pursuant to any dividend reinvestment in the future on the deferred stock units. There is no dividend reinvestment on the other outstanding awards. Outstanding awards had no exercise price. No new awards may be made under the 2003 LTIP.

(b)The number of shares of Con Edison common stock that may be issued pursuant to outstanding awards under the Long Term Incentive Plan approved by the company’s shareholders in 2013 (the “2013 LTIP”) include: (A) outstanding awards made in 2014 and subsequent years (956,834 shares for performance restricted stock units and 67,438 shares for time-based restricted stock units); (B) 292,029 shares covered by outstanding directors’ deferred stock unit awards (which vested upon grant). Amounts do not include shares that may be issued pursuant to any dividend reinvestment in the future on the deferred stock units. There is no dividend reinvestment on the other outstanding awards. The outstanding awards had no exercise price. No new awards may be made under the 2013 LTIP after May 20, 2023.

(c)Shares of Con Edison common stock may be issued under the Stock Purchase Plan until May 19, 2024 (which is 10 years after the date of the annual meeting at which Con Edison’s shareholders approved the plan).

(d)This amount represents shares to be issued to an officer who had elected to defer receipt of these shares until separation from service or later. These shares are issuable pursuant to awards of restricted stock units made in 2000, which vested in 2004.

For additional information about Con Edison’s stock-based compensation, see Note N to the financial statements in Item 8 of this report (which information is incorporated herein by reference).

In accordance with General Instruction G(3) to Form 10-K, other information regarding Con Edison’s Executive Officers may be found in Part I of this report under the caption “Executive Officers of the Registrant.”

192 CON EDISON ANNUAL REPORT 2020

CECONY

Information required by Items 10, 11, 12 and 13 of Part III as to CECONY is omitted pursuant to Instruction (I)(2) to Form 10-K (Omission of Information by Certain Wholly-Owned Subsidiaries).

Fees paid or payable by CECONY to its principal accountant, PricewaterhouseCoopers LLP, for services related to 2020 and 2019 are as follows:

	2020	2019
Audit fees	$3,551,252	$3,645,575
Audit-related fees (a)	1,145,994	—
Total fees	$4,697,246	$3,645,575

(a)Relates to assurance and related service fees that are reasonably related to the performance of the annual audit or quarterly reviews of the company's financial statements that are not specifically deemed “Audit Services.” The major items included in audit-related fees in 2020 are fees related to reviews of system implementations and associated internal controls.

Con Edison’s Audit Committee or, as delegated by the Audit Committee, the Chair of the Committee, approves in advance each auditing service and non-audit service permitted by applicable laws and regulations, including tax services, to be provided to CECONY by its independent accountants.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 193

Part IV

Item 15: Exhibits and Financial Statement Schedules

(a) Documents filed as part of this report:

1. List of Financial Statements – See financial statements listed in Item 8.

2. List of Financial Statement Schedules – See schedules listed in Item 8.

3. List of Exhibits

Exhibits listed below which have been filed previously with the Securities and Exchange Commission pursuant to the Securities Act of 1933 and the Securities Exchange Act of 1934, and which were designated as noted below, are hereby incorporated by reference and made a part of this report with the same effect as if filed with the report. Exhibits listed below that were not previously filed are filed herewith.

194 CON EDISON ANNUAL REPORT 2020

Con Edison

3.1.1	Restated Certificate of Incorporation of Consolidated Edison, Inc. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2017 (File No. 1-14514) as Exhibit 3.1.1)
3.1.2	By-laws of Con Edison, effective as of February 16, 2017. (Designated in Con Edison’s Current Report on Form 8-K, dated February 16, 2017 (File No. 1-14514) as Exhibit 3.1)
4.1.1	Description of Con Edison's Common Shares ($.10 par value). (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2019 (File No. 1-14514) as Exhibit 4.1.1)
4.1.2.1	Indenture, dated as of April 1, 2002, between Con Edison and JP Morgan Chase Bank (formerly known as The Chase Manhattan Bank), as Trustee. (Designated in Con Edison's Registration Statement on Form S-3 of Con Edison (No. 333-102005) as Exhibit 4.1)
4.1.2.2	First Supplemental Indenture, dated as of August 1, 2009, between Con Edison and The Bank of New York Mellon (formerly known as The Bank of New York (successor as trustee to JPMorgan Chase Bank, N.A. (formerly known as JPMorgan Chase Bank))), as Trustee. (Designated in Con Edison’s Registration Statement (No. 333-161018) as Exhibit 4.2)
4.1.2.3	Form of Con Edison’s 2.00% Debentures, Series 2016 A. (Designated in Con Edison's Current Report on Form 8-K, dated May 10, 2016 (File No. 1-14514) as Exhibit 4)
4.1.2.4	Form of Con Edison's 0.65% Debentures, Series 2020 A. (Designated in Con Edison’s Current Report on Form 8-K, dated November 30, 2020 (File No. 1-14514) as Exhibit 4)
4.1.3	Note Assumption and Exchange Agreement, dated as of June 20, 2008, between Con Edison and the institutional investors listed in Schedule I thereto. (Designated in Con Edison’s Current Report on Form 8-K, dated June 20, 2008 (File No. 1-14514) as Exhibit 4)
10.1.1.1	Credit Agreement, dated as of December 7, 2016, among CECONY, Con Edison, O&R, the lenders party thereto and Bank of America, N.A., as Administrative Agent. (Designated in Con Edison’s Current Report on Form 8-K dated December 7, 2016 (File No. 1-14514) as Exhibit 10)
10.1.1.2	Extension Agreement, dated as of January 8, 2018, among CECONY, Con Edison, O&R, the lenders party thereto and Bank of America, N.A., as Administrative Agent. (Designated in Con Edison's Current Report on Form 8-K dated January 8, 2018 (File No. 1-14514) as Exhibit 10)
10.1.1.3	Extension Agreement and First Amendment to Credit Agreement, effective April 1, 2019, among CECONY, Con Edison, O&R, the lenders party thereto and Bank of America, N.A., as Administrative Agent. (Designated in Con Edison’s Current Report on Form 8-K dated April 1, 2019 (File No. 1-14514) as Exhibit 10)
10.1.2.1	Severance Program for Officers of Consolidated Edison, Inc. and its Subsidiaries, as amended, effective as of January 1, 2008. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2008 (File No. 1-14514) as Exhibit 10.1.3)
10.1.2.2	Amendment #1, dated December 19, 2012, to the Severance Program for Officers of Consolidated Edison, Inc. and its Subsidiaries. , dated December 19, 2012, to the Severance Program for Officers of Consolidated Edison, Inc. and its Subsidiaries. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2012 (File No. 1-14514) as Exhibit 10.1.4.2)
10.1.2.3	Amendment to the Severance Program for Officers of Consolidated Edison, Inc. and its Subsidiaries. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2017 (File No. 1-14514 as Exhibit 10.1)
10.1.3.1	The Consolidated Edison, Inc. Stock Purchase Plan, as amended and restated as of May 19, 2014. (Designated in Con Edison’s Current Report on Form 8-K dated May 19, 2014 (File No. 1-14514) as Exhibit 10)
10.1.3.2	Amendment One to The Consolidated Edison, Inc. Stock Purchase Plan. (Designated in Con Edison's Current Report on Form 10-K for the year ended December 31, 2016 (File No. 1-14514) as Exhibit 10.1.3.2)
10.1.3.3	Amendment Two to The Consolidated Edison, Inc. Stock Purchase Plan. (Designated in Con Edison's Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2020 (File No. 1-14514) as Exhibit 10)
10.1.3.4	Amendment Three to The Consolidated Edison, Inc. Stock Purchase Plan.
10.1.4.1	The Consolidated Edison Retirement Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017 (File No. 1-14514) as Exhibit 10.1.1)
10.1.4.2	Amendment to the Consolidated Edison Retirement Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2017 (File No. 1-14514) as Exhibit 10.1.1)
10.1.4.3	Amendment to the Consolidated Edison Retirement Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2017 (File No. 1-14514) as Exhibit 10.1.2)
10.1.4.4	Amendment, dated December 18, 2017, to the Consolidated Edison Retirement Plan .(Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2017 (File No. 1-14514) as Exhibit 10.1.4.2)
10.1.4.5	Amendment to the Consolidated Edison Retirement Plan, effective January 1, 2019. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2019 (File No. 1-14514) as Exhibit 10.1.4.5)
10.1.4.6	Amendment to the Consolidated Edison Retirement Plan, effective August 1, 2019. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2019 (File No. 1-14514) as Exhibit 10.1.4.6)
10.1.4.7	Amendment to the Consolidated Edison Retirement Plan, effective August 1, 2019. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2019 (File No. 1-14514) as Exhibit 10.1.4.7)
10.1.4.8	Amendment to the Consolidated Edison Retirement Plan, effective March 27, 2020. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2020 (File No. 1-14514) as Exhibit 10.2)
10.1.4.9	Amendment to the Consolidated Edison Retirement Plan, effective January 31, 2020.

                                                                                                                         CON EDISON ANNUAL REPORT 2020 195

10.1.5.1	The Consolidated Edison Thrift Savings Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017 (File No. 1-14514) as Exhibit 10.1.2)
10.1.5.2	Amendment, dated December 18, 2017, to the Consolidated Edison Thrift Savings Plan. (Designated in Con Edison's Annual Report on 10-K for the year ended December 31, 2017 (File No. 1-14514) as Exhibit 10.1.5.3
10.1.5.3	Amendment to the Consolidated Edison Thrift Savings Plan, effective January 1, 2019. (Designated in Con Edison's Annual Report on 10-K for the year ended December 31, 2019 (File No. 1-14514) as Exhibit 10.1.5.3)
10.1.5.4	Amendment to the Consolidated Edison Thrift Savings Plan, effective August 1, 2019. (Designated in Con Edison's Annual Report on 10-K for the year ended December 31, 2019 (File No. 1-14514) as Exhibit 10.1.5.4)
10.1.5.5	Amendment to the Consolidated Edison Thrift Savings Plan, effective August 1, 2019. (Designated in Con Edison's Annual Report on 10-K for the year ended December 31, 2019 (File No. 1-14514) as Exhibit 10.1.5.5)
10.1.5.6	Amendment to the Consolidated Edison Thrift Savings Plan, effective January 1, 2020.

    

10.1.6	Consolidated Edison, Inc. Supplemental Defined Contribution Pension Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2019 (File No. 1-14514) as Exhibit 10.1)
10.1.7.1	Consolidated Edison, Inc. Long Term Incentive Plan (2003), as amended and restated effective as of December 26, 2012. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2012 (File No. 1-14514) as Exhibit 10.1.8.1)
10.1.7.2	Form of Stock Option Agreement under the Con Edison Long Term Incentive Plan. (Designated in Con Edison’s Current Report on Form 8-K, dated January 24, 2005, (File No. 1-14514) as Exhibit 10.3)
10.1.7.3	Amendment Number 1, effective July 1, 2010, to the Consolidated Edison, Inc. Long Term Incentive Plan, as amended and restated effective as of January 1, 2008. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2010 as Exhibit 10.1)
10.1.7.4	Amendment Number 2, effective January 1, 2011, to the Consolidated Edison, Inc. Long Term Incentive Plan, as amended and restated effective as of January 1, 2008. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-14514) as Exhibit 10.1.7.5)
10.1.8.1	Consolidated Edison, Inc. Long Term Incentive Plan. (Designated in Con Edison’s Current Report on Form 8-K, dated May 20, 2013 (File No. 1-14514) as Exhibit 10)
10.1.8.2	Amendment No. 1 to the Consolidated Edison, Inc. Long Term Incentive Plan. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2016 (File No. 1-14514) as Exhibit 10.1.7.4)
10.1.8.3	Amendment No. 2 to the Consolidated Edison, Inc. Long Term Incentive Plan. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2016 (File No. 1-14514) as Exhibit 10.1.7.5)
10.1.9	Description of Directors’ Compensation, effective as of December 31,2020.
10.1.10	Letter, dated February 23, 2004, to Robert Hoglund. (Designated in Con Edison’s Current Report on Form 8-K, dated July 21, 2005, (File No. 1-14514) as Exhibit 10.5)
10.1.11	Employment offer letter between Con Edison and Timothy P. Cawley, dated November 19, 2020. (Designated in Con Edison’s Current Report on Form 8-K, dated November 19, 2020 (File No. 1-14514) as Exhibit 10)
10.1.12	Contribution Agreement, dated as of April 20, 2016, by and between Crestwood Pipeline and Storage Northeast LLC and Con Edison Gas Pipeline and Storage Northeast, LLC. (Designated in Con Edison’s Current Report on Form 8-K, dated April 20, 2016 (File No. 1-14514) as Exhibit 10)
10.1.13	Purchase and Sale Agreement, dated as of September 20, 2018, by and between Sempra Solar Portfolio Holdings, LLC and CED Southwest Holdings, Inc. (Designated in Con Edison’s Current Report on Form 8-K, dated September 20, 2018) (File No.1-14514) as Exhibit 2)
10.1.14	Credit Agreement, dated as of November 29, 2018, among Con Edison, the Lenders party thereto and Citibank, N.A, as Administrative Agent. (Designated in Con Edison’s Current Report on Form 8-K, dated December 13, 2018 (File No. 1-14514) as Exhibit 10)
10.1.15	Credit Agreement, dated as of February 11, 2019, among Con Edison, the Lenders party thereto and Mizuho Bank, Ltd. as Administrative Agent. (Designated in Con Edison’s Current Report on Form 8-K, dated February 11, 2019 (File No. 1-14514) as Exhibit 10)
10.1.15.1	First Amendment to Credit Agreement dated as of January 29, 2021, among Con Edison, the Lenders party thereto and Mizuho Bank, Ltd. As Administrative Agent
10.1.16	Confirmation of Forward Sale Transaction, dated May 7, 2019, between Con Edison and Wells Fargo Bank National Association. (Designated in Con Edison’s Current Report on Form 8-K, dated May 7, 2019 (File No. 1-14514) as Exhibit 10)
10.1.17.1	Supplemental Credit Agreement, dated as of April 6, 2020, among Con Edison, the lenders party thereto and Bank of America, N.A., as Administrative Agent. (Designated in Con Edison’s Current Report on Form 8-K, dated April 6, 2020 (File No. 1-14514) as Exhibit 10)
10.1.17.2	Commitment Increase Supplement, dated as of June 26, 2020, among Con Edison, the lenders party thereto and Bank of America, N.A., as Administrative Agent. (Designated in Con Edison’s Current Report on Form 8-K, dated June 26, 2020 (File No. 1-14514) as Exhibit 10)
21.1	Subsidiaries of Con Edison (Designated in Con Edison's Annual Report on Form 10-K for the year ended December 31, 2019 (File No. 1-14514) as Exhibit 21.1)

196 CON EDISON ANNUAL REPORT 2020

23.1	Consent of PricewaterhouseCoopers LLP
31.1.1	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer
31.1.2	Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer
32.1.1	Section 1350 Certifications – Chief Executive Officer
32.1.2	Section 1350 Certifications – Chief Financial Officer
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File - The cover page iXBRL 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.

CECONY

3.2.1.1	Restated Certificate of Incorporation of CECONY filed with the Department of State of the State of New York on December 31, 1984. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2017 (File No. 1-1217) as Exhibit 3.2.1.1)
3.2.1.2	The certificates of amendment of Restated Certificate of Incorporation of CECONY filed with the Department of State of the State of New York on the following dates: May 16, 1988; June 2, 1989; April 28, 1992; August 21, 1992 and February 18, 1998. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2017 (File No. 1-1217) as Exhibit 3.2.1.2)

3.2.2	By-laws of CECONY, effective December 29, 2020.
4.2.1	Participation Agreement, dated as of November 1, 2010, between NYSERDA and CECONY. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-1217) as Exhibit 4.2.2)
4.2.2	Participation Agreement, dated as of November 1, 2004, between NYSERDA and CECONY. (Designated in CECONY’s Current Report on Form 8-K, dated November 9, 2004 (File No. 1-1217) as Exhibit 4.1)
4.2.3	Participation Agreement, dated as of May 1, 2005, between NYSERDA and CECONY. (Designated in CECONY’s Current Report on Form 8-K, dated May 25, 2005 (File No. 1-1217) as Exhibit 4.1)
4.2.4.1	Trust Indenture, dated as of November 1, 2010 between NYSERDA and The Bank of New York Mellon, as trustee. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-1217) as Exhibit 4.2.9)
4.2.4.2	First Supplemental Indenture dated November 2, 2012 to the Trust Indenture dated as of November 1, 2010. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2012 (File No. 1-1217) as Exhibit 4.2.9.2)
4.2.5	Indenture of Trust, dated as of November 1, 2004, between NYSERDA and The Bank of New York. (Designated in CECONY’s Current Report on Form 8-K, dated November 9, 2004 (File No. 1-1217) as Exhibit 4.2)
4.2.6.1	Indenture of Trust, dated as of May 1, 2005, between NYSERDA and The Bank of New York. (Designated in CECONY’s Current Report on Form 8-K, dated May 25, 2005 (File No. 1-1217) as Exhibit 4.2)
4.2.6.2	Supplemental Indenture of Trust, dated as of June 30, 2010, to Indenture of Trust, dated May 1, 2005 between NYSERDA and The Bank of New York Mellon (formerly known as The Bank of New York), as trustee. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-1217) as Exhibit 4.2.14.2)
4.2.7.1	Indenture, dated as of December 1, 1990, between CECONY and The Chase Manhattan Bank (National Association), as Trustee (the “Debenture Indenture”). (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2017 (File No. 1-1217) as Exhibit 4.2.15.1)

4.2.7.2	First Supplemental Indenture (to the Debenture Indenture), dated as of March 6, 1996, between CECONY and The Chase Manhattan Bank (National Association), as Trustee. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2017 (File No. 1-1217) as Exhibit 4.2.15.2)
4.2.7.3	Second Supplemental Indenture (to the Debenture Indenture), dated as of June 23, 2005, between CECONY and JPMorgan Chase Bank, N.A. (successor to The Chase Manhattan Bank (National Association)), as Trustee. (Designated in CECONY’s Current Report on Form 8-K, dated November 16, 2005 (File No. 1-1217) as Exhibit 4.1)

                                                                                                                         CON EDISON ANNUAL REPORT 2020 197

4.2.8 The following forms of CECONY’s Debentures, which are designated as follows:

	Securities Exchange Act File No. 1-1217
Debenture Series	Form	Date	Exhibit
5.875% Series 2003 A	8-K	4/7/2003	4
5.10% Series 2003 C	8-K	6/12/2003	4.2
5.70% Series 2004 B	8-K	2/11/2004	4.2
5.30% Series 2005 A	8-K	3/7/2005	4
5.25% Series 2005 B	8-K	6/20/2005	4
5.85% Series 2006 A	8-K	3/9/2006	4
6.20% Series 2006 B	8-K	6/15/2006	4
5.70% Series 2006 E	8-K	12/1/2006	4.2
6.30% Series 2007 A	8-K	8/28/2007	4
6.75% Series 2008 B	8-K	4/4/2008	4.2
5.50% Series 2009 C	8-K	12/4/2009	4
4.45% Series 2010 A	8-K	6/7/2010	4.1
5.70% Series 2010 B	8-K	6/7/2010	4.2
4.20% Series 2012 A	8-K	3/13/2012	4
3.95% Series 2013 A	8-K	2/25/2013	4
4.45% Series 2014 A	8-K	3/3/2014	4
3.30% Series 2014 B	8-K	11/19/2014	4.1
4.625% Series 2014 C	8-K	11/19/2014	4.2
4.50% Series 2015 A	8-K	11/12/2015	4
3.85% Series 2016 A	8-K	6/14/2016	4
2.90% Series 2016 B	8-K	11/10/2016	4.1
4.30% Series 2016 C	8-K	11/10/2016	4.2
3.875% Series 2017 A	8-K	6/5/2017	4
3.125% Series 2017 B	8-K	11/13/2017	4.1
4.00% Series 2017 C	8-K	11/13/2017	4.2
3.80% Series 2018 A	8-K	5/7/2018	4.1
4.50% Series 2018 B	8-K	5/7/2018	4.2
Floating Rate Series 2018 C	8-K	6/21/2018	4.0
4.00% Series 2018 D	8-K	11/27/2018	4.1
4.65% Series 2018 E	8-K	11/27/2018	4.2
4.125% Series 2019 A	8-K	5/6/2019	4
3.70% Series 2019 B	8-K	11/5/2019	4
3.35% Series 2020 A	8-K	3/26/2020	4.1
3.95% Series 2020 B	8-K	3/26/2020	4.2
3.00% Series 2020 C	8-K	11/13/2020	4

198 CON EDISON ANNUAL REPORT 2020

10.2.1	Settlement Agreement, dated October 2, 2000, by and among CECONY, the Staff of the New York State Public Service Commission and certain other parties. (Designated in CECONY’s Current Report on Form 8-K, dated September 22, 2000 (File No. 1-1217) as Exhibit 10)
10.2.2	The Consolidated Edison Company of New York, Inc. Executive Incentive Plan, as amended and restated as of January 1, 2008. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2008 (File No. 1-1217) as Exhibit 10.2.5)
10.2.3.1	Consolidated Edison Company of New York, Inc. Supplemental Retirement Income Plan, as amended and restated as of January 1, 2009. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2009 (File No. 1-1217) as Exhibit 10.2.6)
10.2.3.2	Amendment, dated December 24, 2015, to the Consolidated Edison Company of New York, Inc. Supplemental Retirement Income Plan (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2015 (File No. 1-1217) as Exhibit 10.2.6.2)
10.2.3.3	Amendment One to the Consolidated Edison Company of New York, Inc. Supplemental Retirement Income Plan. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2016 (File No. 1-1217) as Exhibit 10.2.6.3)
10.2.3.4	Amendment to the Consolidated Edison Company of New York, Inc. Supplemental Retirement Income Plan. (Designated in CECONY's Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017 (File No. 1-1217) as Exhibit 10.2.1.1)
10.2.3.5	Amendment to the Consolidated Edison Company of New York, Inc. Supplemental Retirement Income Plan. (Designated in CECONY's Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017 (File No. 1-1217) as Exhibit 10.2.1.2)
10.2.3.6	Amendment to the Consolidated Edison Company of New York, Inc. Supplemental Retirement Income Plan. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2019 (File No. 1-1217) as Exhibit 10.2.3.6)
10.2.4.1	Deferred Compensation Plan for the Benefit of Trustees of CECONY, as amended effective January 1, 2008. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2008 (File No. 1-1217) as Exhibit 10.2.7)
10.2.4.2	Amendment #1, dated December 26, 2012, to the Deferred Compensation Plan for the Benefit of Trustees of CECONY. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2012 (File No. 1-1217) as Exhibit 10.2.7.2)
10.2.5	CECONY Supplemental Medical Benefits. (Designated in CECONY's Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2017 (File No. 1-1217) as Exhibit 10.2.1)
10.2.6	The Severance Pay Plan for Management Employees of Consolidated Edison Company of New York, Inc. and Orange and Rockland Utilities, Inc. and Other Affiliated Entities That Have Adopted the Plan, effective January 1, 2017. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2016 (File No. 1-1217) as Exhibit 10.2.9)
10.2.7	The Consolidated Edison Company of New York, Inc. Deferred Income Plan, as amended and restated as of January 1, 2019. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2019 (File No. 1-1217) as Exhibit 10.2.7)
10.2.8	The Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan, as amended and restated effective as of January 1, 2018. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2018 (File No. 1-1217) as Exhibit 10.2)
10.2.9.1	Trust Agreement, dated as of March 31, 1999, between CECONY and Mellon Bank, N.A., as Trustee. (Designated in CECONY’s Annual Report on Form 10-K, for the year ended December 31, 2005 (File No. 1-1217) as Exhibit 10.2.13.1)
10.2.9.2	Amendment Number 1 to the CECONY Rabbi Trust, executed October 24, 2003, between CECONY and Mellon Bank, N.A., as Trustee. (Designated in CECONY’s Annual Report on Form 10-K, for the year ended December 31, 2005 (File No. 1-1217) as Exhibit 10.2.13.2)
23.2	Consent of PricewaterhouseCoopers LLP
31.2.1	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer
31.2.2	Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer
32.2.1	Section 1350 Certifications – Chief Executive Officer
32.2.2	Section 1350 Certifications – Chief Financial Officer
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File - The cover page iXBRL tags are embedded within the inline XBRL document

                                                                                                                         CON EDISON ANNUAL REPORT 2020 199

Item 16: Form 10-K Summary

None.

Supplemental Information to be Furnished With Reports Filed Pursuant to Section 15(d) of the Securities Exchange Act of 1934 by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Securities Exchange Act of 1934.

No annual report to security holders covering CECONY’s last fiscal year has been sent to its security holders. No proxy statement, form of proxy or other proxy soliciting material has been sent to CECONY’s security holders during such period.

200 CON EDISON ANNUAL REPORT 2020

Signatures

Pursuant to the requirements of Section 13 or 15(d) 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, on February 18, 2021.

Consolidated Edison, Inc.

Consolidated Edison Company of New York, Inc.

By	/s/ Robert Hoglund
	Robert Hoglund Senior Vice President and Chief Financial Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant, and in the capacities indicated, on February 18, 2021.

Signature	Registrant	Title
/s/ Timothy P. Cawley	Con Edison	President, Chief Executive Officer and Director (Principal Executive Officer)
Timothy P. Cawley	CECONY	Chief Executive Officer and Trustee (Principal Executive Officer)
/s/ Robert Hoglund	Con Edison	Senior Vice President and Chief Financial Officer (Principal Financial Officer)
Robert Hoglund	CECONY	Senior Vice President and Chief Financial Officer (Principal Financial Officer)
/s/ Joseph Miller	Con Edison	Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)
Joseph Miller	CECONY	Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)
/s/ John McAvoy	Con Edison CECONY	Non-Executive Chairman of the Board, Director Non-Executive Chairman of the Board, Trustee
John McAvoy
/s/ George Campbell Jr.	Con Edison CECONY	Director Trustee
George Campbell Jr.
/s/ Ellen V. Futter	Con Edison CECONY	Director Trustee
Ellen V. Futter
/s/ John F. Killian	Con Edison CECONY	Director Trustee
John F. Killian
/s/ Karol V. Mason	Con Edison CECONY	Director Trustee
Karol V. Mason
/s/ Dwight A. McBride	Con Edison CECONY	Director Trustee
Dwight A. McBride
/s/ William J. Mulrow	Con Edison CECONY	Director Trustee
William J. Mulrow
/s/ Armando J. Olivera	Con Edison CECONY	Director Trustee
Armando J. Olivera
/s/ Michael W. Ranger	Con Edison CECONY	Director Trustee
Michael W. Ranger
/s/ Linda S. Sanford	Con Edison CECONY	Director Trustee
Linda S. Sanford
/s/ Deirdre Stanley	Con Edison CECONY	Director Trustee
Deirdre Stanley
/s/ L. Frederick Sutherland	Con Edison CECONY	Director Trustee
L. Frederick Sutherland

                                                                                                                         CON EDISON ANNUAL REPORT 2020 201

EX-10.1.3.4

Exhibit 10.1.3.4

AMENDMENT THREE TO THE

CONSOLIDATED EDISON, INC.

STOCK PURCHASE PLAN

Exhibit 10.1.3.4

WHEREAS, the Consolidated Edison, Inc. Stock Purchase Plan, as amended and restated as of May 19, 2014, and as further amended by Amendment One to the Stock Purchase Plan (the “Stock Purchase Plan”), provides a means for employees of Consolidated Edison, Inc.’s affiliated companies and members of their boards of directors to purchase shares of stock of Consolidated Edison, Inc.; and

WHEREAS, pursuant to Article 11, Termination and Modifications: Responsibility of Company and Plan Director, the Vice President – Human Resources has the authority to amend certain provisions of the Stock Purchase Plan to facilitate the administration of the Stock Purchase Plan; and

WHEREAS, the Vice President – Human Resources is authorized to execute the specified amendments to the Stock Purchase Plan, her execution to be evidence conclusively of her approval thereof;

NOW, THEREFORE, the Stock Purchase Plan is amended as set forth below:

Exhibit 10.1.3.4

1.Article 4, subsection (a)(i), is amended and restated in its entirety as follows, effective as of January 1, 2021:

(i)“For Shares purchases other than from the Company, the Participating Employer shall pay over the amount of each payroll deduction so authorized to the Agent, for the Account of the Employee.”

2.The first sentence of Article 4, subsection (a)(ii), is amended and restated as follows, effective as of January 1, 2021:

(ii)“For Shares newly issued by or purchased directly from the Company, the Participating Employer shall pay over the amount of each payroll deduction so authorized to the Company, for the purchase of Shares for the Employee.”

3.Article 6, subsection (c)(ii) is amended and restated in its entirety as follows, effective as of September 1, 2020:

(ii)“If the Shares are purchased other than from the Company, the purchase price per share will be the closing stock price on the last business day of the Purchase Period at which Shares were traded on the New York Stock Exchange.”

Except as expressly modified in accordance with the provisions of this Amendment Three to the Stock Purchase Plan, all other terms and

Exhibit 10.1.3.4

conditions set forth in the Stock Purchase Plan will remain in full force and effect.

IN WITNESS WHEREOF, the undersigned has caused this instrument to be executed on this 24th day of December, 2020.

/s/ Nancy Shannon

Nancy Shannon

Vice President of Human Resources of

Consolidated Edison Company of New York, Inc.

EX-10.1.4.9

Exhibit 10.1.4.9

AMENDMENT TO THE

CONSOLIDATED EDISON

RETIREMENT PLAN

1

Exhibit 10.1.4.9

WHEREAS, pursuant to Article X, Amendment, Merger and Termination, Section 10.01, Amendment of the Plan, the Plan Administrator has the authority to amend certain provisions of the Consolidated Edison Retirement Plan (the “Retirement Plan”); and

WHEREAS, the Vice President – Human Resources, as Plan Administrator, is authorized to execute the specified amendments to the Retirement Plan, her execution to be evidence conclusively of her approval thereof;

NOW, therefore, the Retirement Plan is amended as set forth below:

2

Exhibit 10.1.4.9

Amendment Number 1

    The Title Page of the Retirement Plan is amended effective January 1, 2020, by adding the following new at the end:

    28.    Amended, effective January 1, 2020, to take into account the 2019 – 2023 Memorandum of Understanding between Local Union 503 of the International Brotherhood of Electrical Workers, AFL-CIO and changes approved by the O&R Board of Directors for O&R Management Participants that changes the Pivot Years for O&R Management Participants and O&R Hourly Participants – One Pivot Year Update for Those Who Retire After January 1, 2020 and One Pivot Year Update for Those Who Retire After January 1, 2023.

    29.    Amended to reflect clarifying language regarding the definition of Shift Premium Compensation, effective August 31, 2015.

    30.    Effective January 1, 2020, amended to reflect an increase in supplemental payments between ages 60 and 62 for O&R Participants.

    31.    Amended to reflect clarifying language regarding disability pension allowance.

    32.    Amended for a special retirement election period due to the COVID-19 pandemic.

Amendment Number 2

    The Introduction is amended effective January 1, 2020, to add at the end of that Section:

    As a result of the Board of Directors and Board of Trustees approval of the 2019-2023 Memorandum of Understanding between the International Brotherhood of Electrical Workers, AFL-CIO and its Local 503 and O&R, the Retirement Plan is amended effective January

3

Exhibit 10.1.4.9

1, 2020, to provide for (i) two pivot year updates for O&R Hourly Participants who retire after January 2020 (2016 Pivot Year) and after January 2023 (2019 Pivot Year), (ii) an increase the pension supplement for an O&R Hourly Employee to $1,200, (iii) a lump sum automatic form of payment option and (iv) permit an irrevocable election to transfer out of the Retirement Plan and instead be covered by the Defined Contribution Pension Formula in the Thrift Savings Plan. The changes regarding pivot years and pension supplement described in this paragraph also were made for O&R Management Participants.

    The Retirement Plan was also amended to reflect a special retirement election period that was offered to all Participants from May 1, 2020 through July 1, 2020. During this period, all Participants were offered the opportunity to make an election to retire effective July 1, 2020.

Amendment Number 3

    Article I, Definitions, Section 1.07, Annual Basic Straight-Time Compensation, is amended by adding a new subsection (h) to the end as follows:

    On or after August 31, 2015, Annual Basic Straight Time Compensation for (i) a CECONY Management Participant; (ii) an O&R Management Participant or (iii) a CECONY Management Employee or an O&R Management Employee covered under the cash balance pension formula (and referred to as a CEI Participant), includes “Shift Premium Compensation” that is paid to him or her on or after August 31, 2015. “Shift Premium Compensation” is additional salary paid to a CECONY Management Participant, O&R Management Participant, or a CECONY Management Employee or O&R Management Employee

4

Exhibit 10.1.4.9

covered under the cash balance pension formula for a night, midnight, Sunday or holiday shift that is part of his or her regular work schedule.

Amendment Number 4

    Article I, Definitions, Section 1.09, Annual O&R Management Compensation, is amended by adding the following to the end as follows:

    On or after August 31, 2015, Annual O&R Management Compensation includes “Shift Premium Compensation” paid to an O&R Management Employee on or after August 31, 2015. “Shift Premium Compensation” is additional salary paid to an O&R Management Participant or O&R Management Employee covered under the cash balance pension formula for a night, midnight, Sunday or holiday shift that is part of his or her regular work schedule.

Amendment Number 5

    Article II, Participant, is amended effective January 1, 2020, to add a new Subsection 2.10, Pension Choice for a Participant who is a Member of Local 503, and the current Section 2.10 is renumbered as Section 2.11:

    (a)    Effective July 1, 2020, a Pension Choice will be given to each O&R Hourly Employee who is a member of Local 503 and covered under the Cash Balance Pension Formula. Each such O&R Employee will be given an opportunity to make an irrevocable election to transfer out of the Retirement Plan and instead be covered by the Defined Contribution Pension Formula in the Thrift Savings Plan.

(b)     The election period for such an O&R Hourly Employee will begin on July 1, 2020 and will end on May 31, 2023. The O&R Hourly

5

Exhibit 10.1.4.9

Employee may make her or his election at any time during this election period.

    (c)    If an O&R Hourly Employee elects to transfer out of the Retirement Plan and into the Defined Contribution Pension Formula, his or her active participation in the Retirement Plan will terminate at the end of the calendar quarter in which he or she submits his or her election form.

    (d)    The election by an O&R Hourly Employee to transfer out of the Retirement Plan is irrevocable and remains in effect for as long as he or she is an Employee, Eligible Employee or providing services to CEI or any Affiliate. A new election is not available if the O&R Hourly Employee is rehired or reinstated following any break in service or termination of employment.

    (e)    The O&R Hourly Employee will begin participation in the Defined Contribution Pension Formula on the first day of the calendar quarter immediately following the end of the calendar quarter in which he or she submitted the election form or as soon as administratively practicable.

    (f)    An O&R Hourly Employee who makes an election to terminate active participation in the Retirement Plan will receive no additional compensation credits to his or her Cash Balance Pension benefit in the Retirement Plan. His or her Cash Balance Pension benefit remains in the Retirement Plan and will not be transferred to the Thrift Savings Plan.

    (g)    An O&R Hourly Employee who makes an election to terminate active participation in the Retirement Plan will continue to receive quarterly interest credits on his or her Cash Balance Pension

6

Exhibit 10.1.4.9

benefit until the date that he or she begins distribution of his or her Cash Balance Pension benefit from the Retirement Plan.

Amendment Number 6

    Article II, Participant, Section 2.11, Pension Choice, will be amended effective August 1, 2019 to read as follows:

As of August 1, 2019, the following chart summarizes which Participant Group has a Pension Choice election and the time period in which such Participant Group may exercise such Pension Choice election. The following chart also summarizes which Participant Group was offered a limited time period in which to change a prior election to transfer out of the Defined Contribution Pension Formula of the Thrift Savings Plan and back into the Retirement Plan and the time period in which such election must be made:

	Participant Group	Date Pension Choice Begins	Date Pension Choice Ends
1.	Local 3 – Each Local 3 member hired before June 30, 2013, and covered under the Cash Balance Formula	No later than January 1, 2014	December 31, 2015
2.	Local 3 – Each Local 3 member hired on or after June 30, 2013	Date of hire	60 days after date of hire
3.	Local 503 - Each member of Local 503 hired on or after January 1, 2010, and covered under the Cash Balance formula	January 1, 2015, end	December 31, 2015
4.	Local 1-2 – Each member of Local 1-2, hired between July 1, 2012, and June 25, 2016, and covered under the Cash Balance Pension Formula	No later than January 1, 2017	June 20, 2020

7

Exhibit 10.1.4.9

5.	Local 1-2 – Each member of Local 1-2, hired on or after June 25, 2016	Date of hire	60 days after date of hire
6.	CECONY or O&R Management Employees or CEI Affiliate Employees– Each CECONY, O&R management employee or hired on or after January 1, 2001 and covered under the Cash Balance Pension formula	June 1, 2017	December 31, 2021
7.	Local 503 – Each member of Local 503 covered under the Cash Balance Pension Formula	July 1, 2020	May 31, 2023
	Participant Group	Date Period to Undo Transfer Out of Retirement Plan Begins	Date Period to Undo Transfer Out of Retirement Plan Ends
7.	Local 3 – Each Local 3 member hired before June 30, 2013, and covered under the Cash Balance Formula who previously elected to transfer out of the Retirement Plan and into the Defined contribution Pension Formula of the Thrift Savings Plan	August 1, 2019	October 31, 2019
8.	Local 503 - Each member of Local 503 hired on or after January 1, 2010, and covered under the Cash Balance formula who previously elected to transfer out of the Retirement Plan and into the Defined contribution Pension Formula of the Thrift Savings Plan	August 1, 2019	October 31, 2019
9.	Local 1-2 – Each member of Local 1-2, hired between July 1, 2012, and June 25, 2016, and covered under the Cash Balance Pension Formula who previously elected to transfer out of the Retirement Plan and into the Defined contribution Pension Formula of the Thrift Savings Plan	August 1, 2019	October 31, 2019

8

Exhibit 10.1.4.9

10. CECONY or O&R Management Employees or CEI Affiliate Employees– Each CECONY, O&R management employee or hired on or after January 1, 2001 and covered under the Cash Balance Pension formula who previously elected to transfer out of the Retirement Plan and into the Defined contribution Pension Formula of the Thrift Savings Plan August 1, 2019 October 31, 2019

Amendment Number 7

Article IV, Eligibility for and Amount of Benefits, Section 4.04, Early Retirement, subsection (c), O&R Participants, subsection (4) is amended effective January 1, 2020, in its entirety to read as follows:

    Supplemental Payment between Ages 60 and 62. A supplemental payment shall be paid to a retired O&R Participant whose Early Retirement Pension Allowance commencement date occurs on or after the date on which the O&R Participant attains age sixty (60) but prior to the Participant’s attaining age sixty-two (62). Effective for an O&R Management Participant or O&R Participant who retires on or after January 1, 2020, the supplement payment will be increased from one thousand and fifty dollars ($1,050) a month to one thousand two hundred dollars ($1,200) a month. The monthly supplement payments will cease with the payment made on the earlier of the first day of the month in which occurs the retired Participant’s death or attainment of age sixty-two (62). The monthly supplemental payments will be paid only to a retired O&R Participant who is eligible as set forth herein and shall not be subject to optional forms of payment or Spouse’s or vested O&R Participant Spouse’s Allowances. The monthly supplemental payments are not part of the retired O&R Participant’s monthly Pension Allowance and are not subject to the pension benefit adjustments, but

9

Exhibit 10.1.4.9

are subject to cessation in the event of re-employment which results in cessation of the retired O&R Participant’s monthly Pension Allowance.    

Amendment Number 8

    Article IV, Eligibility and Amount of Benefits, Section 4.06, Disability Pension Allowance – CECONY Participants, subsection (a) is amended in its entirety to read as follows:

Social Security Disability.

If a CECONY Participant terminates active employment because of a Disability and has at least five Years of Vesting Service, he or she may elect to be treated as if he or she remained in active employment until the earliest of: (i) the end of his or her Disability; (ii) date of commencement of any gainful employment or any self-employment or any activity of like nature in which the Participant receives wages or earned income; (iii) date of death, (iv) Normal Retirement Date, or (v) Early Retirement Date, if such CECONY Participant elects to stop being treated as actively employed and to commence a Pension Allowance prior to the Normal Retirement Date. The Pension Allowance of such CECONY Participant shall be determined as if his or her Annual Basic Straight Time Compensation at the point of his or her actual termination of active employment was his or her Annual Compensation for all future years. For that period of "deemed employment," Annual Compensation shall not include an Annual Variable Pay Award.

Amendment Number 9

Article V, Automatic Form of Payment, Section 5.02, Optional Forms of Payment, subsection (c), O&R Participant, is amended by adding the following subsections 10 and 11 at the end of that section:

10

Exhibit 10.1.4.9

    10. Effective on and after January 1, 2020, an O&R Hourly Participant covered by the career average pay formula may elect to receive her or his Pension Allowance otherwise payable to her or him in the form of a Lump Sum option. The election to receive a Lump Sum may be made at any time subsequent to the O&R Hourly Participant’s termination of employment, so long as the O&R Hourly Participant has made no other election. If the O&R Hourly Participant is married at both the time of making the election and the Annuity Starting Date, she or he must have spousal consent.

    11. An O&R Hourly Participant who, as of January 1, 2020, has deferred and has not begun to receive her or his Pension Allowance may elect his or her benefit in the form of a Lump Sum at the time he or she elects to commence his or her retirement benefit. Such deferred vested participant must be eligible to commence their retirement benefit prior to the election of the Lump Sum payment option

Amendment Number 10

    Article V, Automatic Form of Payment, Section 5.03, Election of Options, subsection (f), Revocation, is amended by adding the following to the end as follows:    

Due to the COVID-19 pandemic, a special retirement election period was offered from May 1, 2020 – July 1, 2020. During this period, all Participants were offered the opportunity to make an election to retire effective July 1, 2020. Spousal consent was required for married Participants who elected certain optional forms of benefit. For retirement elections made during this period, married Participants did not have the option of naming a non-spouse beneficiary for any form of benefit. Participants could elect to receive their benefit in any form normally available to them under the Plan, except that solely for the

11

Exhibit 10.1.4.9

duration of this special retirement election period, all CECONY Rule of 75 Participants could also elect to receive their benefit in the form of a Cash Out (including Participants who made a regular retirement election during this period to retire on June 1, 2020). If a Participant made a retirement election during the special retirement election period and subsequently died prior to the election becoming effective on July 1, 2020, the election was honored consistent with this Section 5.03(f). If a Participant elected to retire during the special election period but remained employed beyond July 1, 2020, the election made during the special election period was rendered null and void, and all regular Plan rules regarding retirement elections were applicable again as of July 1, 2020.

Amendment Number 11

    Appendix F, Normal Retirement Formulas for CECONY Weekly Participants, CECONY Management Participants and O&R Participants,Section F.3, Benefit Formula for O&R Participants,section F. 3. A is amended effective January 1, 2020, by adding new subsections (h) and (i), and renumbering the remaining sections as follows:

    (j)    For an O&R Management Participant or O&R Hourly Participant who retires on and after January 1, 2020:

(i)Calculation of “future service”: 2% of O&R Hourly Participant’s Annual Compensation received during his or her Accredited Service for each Year of Accredited Service after December 31, 2015, provided that the amount shall be computed as if Accredited Service had continued and he or she had received Annual Compensation at the rate being

12

Exhibit 10.1.4.9

paid to him or her immediately prior to retirement for an

additional two (2) years after retirement, plus

(ii)Calculation of “past service”: 1 ½% of O&R Hourly Participant’s Annual Compensation as of January 1, 2016, multiplied by (y) the number of Years of Accredited Service prior to January 1, 2016, but not less than

(iii)The Pension Allowance accrued up to January 1, 2016.

(k)    For an O&R Management Participant or O&R Hourly Participant who retires on and after January 1, 2023:

(i)Calculation of “future service”: 2% of O&R Hourly Participant’s Annual Compensation received during his or her Accredited Service for each Year of Accredited Service after December 31, 2018, provided that the amount shall be computed as if Accredited Service had continued and he or she had received Annual Compensation at the rate being paid to him or her immediately prior to retirement for an additional two (2) years after retirement, plus

(ii)Calculation of “past service”: 1 ½% of O&R Hourly Participant’s Annual Compensation as of January 1, 2019, multiplied by (y) the number of Years of Accredited Service prior to January 1, 2019, but not less than

(iii)The Pension Allowance accrued up to January 1, 2019.

13

Exhibit 10.1.4.9

IN WITNESS WHEREOF, the undersigned has caused this instrument to be executed on this 31st day of December, 2020.

/s/ Nancy Shannon

Nancy Shannon

Vice President of Human Resources of

Consolidated Edison Company of New York, Inc.

And the Plan Administrator of the Retirement Plan

14

EX-10.1.5.6

Exhibit 10.1.5.6

AMENDMENT TO THE CONSOLIDATED EDISON THRIFT SAVINGS PLAN

Exhibit 10.1.5.6

Whereas, the Board of Directors and the Board of Trustees have the authority to amend in whole or in part any or all of the provisions of the Consolidated Edison Thrift Savings Plan (the “Thrift Savings Plan”); and

Whereas, pursuant Section 10.02 Authority of the Plan Administrator, the Vice President – Human Resources (an “Authorized Officer”) is authorized to execute the specified amendments to the Thrift Savings Plan in such form as the Authorized Officer may approve, her execution to be evidence conclusively of her approval thereof.

Now, therefore, the Thrift Savings Plan is amended as set forth below:

1

Exhibit 10.1.5.6

Amendment Number 1

The Title Page to the Thrift Savings Plan is amended by adding at the end of the Amendment List the following:

•Amended, effective January 1, 2018, to include shift differential in the definition of Compensation for a CECONY Management Employee or O&R Management Employee.

•Amended, effective June 21, 2020, to take into account changes made by the 2020-2024 Collective Bargaining Agreement for The Utility Workers Union of America, AFL-CIO, Local 1-2.

•Amended, effective January 21, 2021, to take into account increases to the auto-enrollment and auto-escalation feature for all Eligible Employees within the CEI controlled group.

•Amended, effective January 1, 2020, to take into account changes made by the 2019-2023 Collective Bargaining Agreement for the International Brotherhood of Electrical Workers, Local 503.

•Amended, effective January 1, 2020, to limit True-Up Contributions for any Eligible Employee who exceeds the annual addition limitations set forth in the Internal Revenue Code.

•Amended, effective January 1, 2020, to incorporate final IRS regulations issued on September 23, 2019 regarding Hardship Withdrawals.

Amendment Number 2

The Introduction is amended, to add to the end of that Section:

    Having the authority to amend the Thrift Savings Plan when necessary or desirable for uniform or efficient administration, the Plan Administrator has elected to exercise her authority and amend the Thrift Savings Plan as follows:

i.for clarification, to reflect that Compensation for a CECONY Management Employee or an O&R Management Employee includes any shift differential that is paid to him or her after January 1, 2018.

ii.to reflect an increase in the contribution rate for each CECONY Management Employee, O&R Management Employee, CET

2

Exhibit 10.1.5.6

Employee or CEB Employee automatically enrolled to (a) three (3) percent of straight-time pay and (b) an increase in the automatic escalation feature to fifteen (15) percent

iii.to reflect that if any portion of the True-up Contribution to which a Local 1-2 Employee, Local 3 Employee, CECONY Management Participant, CEI Participant, O&R Management Participant or CET Participant would otherwise be entitled would cause the annual additions to the Account Balance of each such participant to exceed the limitations described in the Internal Revenue Code, then such portion of the True-up Contributions will not be made

iv.(a) to incorporate a new type of expense for hardship distributions incurred due to a disaster declared by the Federal Emergency Management Agency (FEMA), (b) to eliminate the requirement to take a loan from the Thrift Savings Plan prior to taking a hardship withdrawal and (c) to eliminate the restriction that participants cannot make new contributions to the Thrift Savings Plan within six (6) months of the hardship distribution.

    The Thrift Savings Plan, in accordance with the 2020-2024 Collective Bargaining Agreement between the Utility Workers Union of America, AFL-CIO, Local 1-2 and Consolidated Edison Company of New York, Inc., is amended for each CECONY Weekly Employee who is a member of Local 1-2 as follows:

i.to reflect new Weekly and Annual Maximum Employer Matching Contributions for employees covered under the Final Average Pay Formula

ii.to reflect new Weekly and Annual Maximum Employer Matching Contribution for employees covered Under the Cash Balance Pension Formula or the Defined Contribution Pension Formula

iii.effective July 1, 2020, to reflect an increase in the contribution rate for each employee automatically enrolled to three (3) percent of straight-time pay

3

Exhibit 10.1.5.6

iv.effective July 1, 2020, to reflect an increase in the automatic escalation feature to fifteen (15) percent    

The Thrift Savings Plan, in accordance with the 2019-2023 Collective Bargaining Agreement between the International Brotherhood of Electrical Workers, AFL-CIO and its Local 503, and Orange and Rockland Utilities, Inc., is amended for each O&R Hourly Employee as follows:

i.effective January 1, 2020, he or she may make Roth Contributions

ii.effective January 1, 2020, Employer Matching Contributions will be 100% of the first 4% of Compensation contributed to the Plan during each payroll period for any employee covered under the Cash Balance Pension Formula in the Retirement Plan or the Defined Contribution Pension Formula and who elects to make Pre-Tax Contributions or Roth Contributions

Amendment Number 3

    Article I, Definitions, Section 1.31, Compensation, subsection (c) is amended effective January 1, 2018 by adding additional language to the end as follows:

    Effective January 1, 2018, Compensation for a CECONY Management Employee or an O&R Management Employee shall also include any shift differential that is paid to him or her after January 1, 2018; and

Amendment Number 4

    Article III, Contributions, Section 3.01, Contribution Election, subsection (c), O&R Hourly Participant, is amended effective January 1, 2020, by deleting that subsection in its entirety and replacing it with the following:

    An O&R Hourly Participant may elect to reduce his or her Compensation by at least 1% and not more than 50%, in multiples of 1%, and have that amount contributed to the Thrift Savings Plan as Pre-Tax Contributions, or effective January 1, 2020, as Roth Contributions.At the time an O&R Hourly Participant elects a contribution amount, he or she will designate which portion is to be Pre-

4

Exhibit 10.1.5.6

Tax Contributions or Roth Contributions. Pre-Tax Contributions and Roth Contributions are to be further limited as provided below and in Article 8.

Amendment Number 5

    Article III, Contributions, Section 3.05, Employer Matching Contributions - Participating Contributions Eligible for Employer Matching Contributions, subsection (c), New Rule for Local 1-2 – January 1, 2018, is amended effective January 1, 2021, by adding a new subsection (vi) to reflect new Weekly and Annual Maximum Employer Matching Contributions for Local 1-2 Employees Covered Under the Final Average Pay Formula in the Retirement Plan as follows:

(vi)    Effective January 1, 2021, and each January 1st thereafter, the Weekly and Annual Maximum Employer Matching Contributions will be as follows:

Calendar Year Beginning	Weekly Maximum Employer Matching Contribution	Annual Maximum Employer Matching Contribution
January 1, 2021	$34.13	$1,775
January 1, 2022	$35.58	$1,850
January 1, 2023	$37.02	$1,925
January 1, 2024	$38.46	$2,000

Amendment Number 6

    Article III, Contributions, Section 3.05, Employer Matching Contributions - Participating Contributions Eligible for Employer Matching Contributions, subsection (e) is amended effective January 1, 2021, by adding new Weekly and Annual Maximum Employer Matching Contribution for Local 1-2 Employee Covered Under the Cash Balance Pension Formula or the Defined Contribution Pension Formula as follows:

Effective January 1, 2021, and each January 1st thereafter, the Weekly and Annual Maximum Employer Matching Contribution for a Local 1-2 Employee covered under the Cash Balance Pension Formula or the Defined Contribution Pension Formula will be as follows:

5

Exhibit 10.1.5.6

Calendar Year Beginning	Weekly Maximum Employer Matching Contribution	Annual Maximum Employer Matching Contributions
January 1, 2021	$68.27	$3,550
January 1, 2022	$71.15	$3,700
January 1, 2023	$74.04	$3,850
January 1, 2024	$76.92	$4,000

Amendment Number 7

    Article III, Contributions, Section 3.05, Employer Matching Contributions - Participating Contributions Eligible for Employer Matching Contributions, subsection (f), True-Up Company Contribution for Local 1-2 Employee, is amended effective January 1, 2020, by adding the following to the end of the last paragraph:

    If any portion of the True-Up Contribution to which a Local 1-2 Employee would otherwise be entitled under this section would cause the annual additions to the Account Balance of such Local 1-2 Employee to exceed the limitations described in Section 8.04, then such portion of the True-Up Contribution shall not be made.

Amendment Number 8

    Article III, Contributions, Section 3.05, Employer Matching Contributions - Participating Contributions Eligible for Employer Matching Contributions, subsection (m), True-Up Company Contribution for Local 3 Employee, is amended effective January 1, 2020, by adding the following to the end of the last paragraph:

     If any portion of the True-Up Contribution to which a Local 3 Employee would otherwise be entitled under this section would cause the annual additions to the Account Balance of such Local 3 Employee to exceed the limitations described in Section 8.04, then such portion of the True-Up Contribution shall not be made.

6

Exhibit 10.1.5.6

Amendment Number 9

    Article III, Contributions, Section 3.05, Employer Matching Contributions - Participating Contributions Eligible for Employer Matching Contributions, subsection (n)CECONY Management Participant and CEI Participant, subsection(iv) is amended effective January 1, 2020, by adding the following to the end:

    If any portion of the True-up Contribution to which a CECONY Management Participant or CEI Participant would otherwise be entitled under this section would cause the annual additions to the Account Balance of such CECONY Management Participant or CEI Participant to exceed the limitations described in Section 8.04, then such portion of the True-Up Contribution shall not be made.

Amendment Number 10

    Article III, Contributions, Section 3.05, Employer Matching Contributions - Participating Contributions Eligible for Employer Matching Contributions, subsection (n), CECONY Management Participant and CEI Participant, subsection(vii) is amended effective January 1, 2020, by adding the following to the end:

    If any portion of the True-Up Contribution to which a CECONY Management Participant, O&R Management Participant or CET Participant would otherwise be entitled under this section would cause the annual additions to the Account Balance of such CECONY Management Participant, O&R Management Participant or CET Participant to exceed the limitations described in Section 8.04, then such portion of the True-Up Contribution shall not be made.

Amendment Number 11

    Article III, Contributions, Section 3.05, Employer Matching Contributions - Participating Contributions Eligible for Employer Matching Contributions, subsection (o)O&R Hourly Participant, is amended effective January 1, 2020, by adding the following new subsection (iii):

    (iii)    Effective as of January 1, 2020, O&R will contribute on behalf of each O&R Hourly Employee who, whether by design or election, is covered under the Cash Balance Pension Formula in the Retirement Plan or the Defined Contribution Pension Formula, and who elects to make Pre-Tax Contributions or Roth

7

Exhibit 10.1.5.6

Contributions, an amount equal to 100% of the first 4% of Compensation contributed to the Plan during each payroll period.

Amendment Number 12

    Article III, Contributions, Section 3.12, Auto Enrollment Feature – For Local 1-2, subsection (a), Auto Enrollment Feature For a Local 1-2 Employee hired on or after January 1, 2018, is amended effective July 1, 2020, by adding the following new subsection (v) to the end:

        (v)    The contribution rate for each Local 1-2 Employee automatically enrolled after July 1, 2020 in accordance with Section 3.12(a)(i) above will be set to equal three (3) percent of his or her straight-time pay.

Amendment Number 13

    Article III, Contributions, Section 3.13, Auto Escalation Feature – For Local 1-2, subsection (b), Auto Escalation Feature, Effective July 2019, for Each Local 1-2 Employee Contributing Less Than 10%, is amended effective July 1, 2020, by adding the following new subsection (iv) to the end:

         (iv) Effective July 1, 2020, the automatic escalation feature for Local 1-2 Employees will increase to fifteen (15) percent. Effective with the first payroll period in July of 2021, and in each July thereafter, the contribution rate for each Local 1-2 Employee who has not opted out of the Auto Escalation Feature and is contributing less than fifteen (15) percent to the Thrift Savings Plan will be automatically increased by one (1) percentage point, until the Local 1-2 Employee’s rate reaches fifteen (15) percent.

Amendment Number 14

Article III, Contributions, Section 3.13, Auto Escalation Feature – For Local 1-2, subsection (c), Notices about the Auto Enrollment Feature and the Auto Escalation Feature, is amended effective July 1, 2020, by adding the following new subsection (viii) to the end:

        (viii)    Each Local 1-2 Employee who was hired before July 1, 2020, and is not participating or is participating, but at a contribution rate of less than 15%, will receive a Notice about the Auto Enrollment Feature or a Notice about

8

Exhibit 10.1.5.6

the Auto Escalation Feature, respectively, no less than 60 days prior to January 1, 2020.

Amendment Number 15

    Article III, Contributions, Section 3.14, Auto Enrollment Feature – For CECONY Management Employee, O&R Management Employee, CET Employee, or CEB Employee, subsection (a), Auto Enrollment Feature for a CECONY Management Employee, O&R Management Employee, CET Employee or CEB Employee, who, as of April 1, 2017, is neither participating in the 401(k) Formula nor making After-Tax Contributions to the Thrift Savings Plan, is amended effective January 1, 2021, by adding a new subsection (v) to the end:

    (v)    Effective for each CECONY Management Employee, O&R Management Employee, CET Employee, or CEB Employee automatically enrolled on or after January 1, 2021, the contribution rate will be set to equal three (3) percent of his or her straight-time pay.

Amendment Number 16

    Article III, Contributions, Section 3.15, Auto Escalation Feature – CECONY Management Participant, O&R Management Participant, CEB Participant or CET Participant, subsection (a) is amended effective July 1, 2020, by adding the following new subsection (ix) to the end:

    (ix)    Effective January 1, 2021, the automatic escalation feature for CECONY Management Participants, O&R Management Participants, CEB Participants and CET Participants will increase to fifteen (15) percent. Effective with the first payroll period in January of 2021, and in each January thereafter, the contribution rate for each such Participant who has not opted out of the Auto Escalation Feature and is contributing less than fifteen (15) percent will be automatically increased by one (1) percentage point, until his or her rate reaches fifteen (15) percent. The Auto Escalation Feature is intended and designed to promote the participation of each Participant at a rate of 15%. Each CECONY Management Participant, O&R Management Participant, CET Participant or CEB Participant will receive a Notice about the increased Auto Escalation Feature no less than 30 days prior to January 1, 2021, and then, thereafter, no less than 30

9

Exhibit 10.1.5.6

days prior to the first payroll date the automatic contribution increase commences.

Amendment Number 17

    Article VII, Distributions, Withdrawals and Forfeitures, Section 7.04, Hardship Withdrawals, subsection (a), Immediate and Heavy Financial Need, is amended effective January 1, 2020, by adding the following new subsections (vii) and (viii) and renumbering subsequent subsections accordingly:

    (vi)    expenses for the repair of damage to the Participant’s principal residence that would qualify for the casualty deduction under Code Section 165 (determined without regard to whether the loss exceeds 10% of adjusted gross income or Code Section 165(h)(5));

    (vii)    expenses and losses (including loss of income) incurred by the Participant on account of a federally declared disaster, provided that the Participant’s residence or principal place of employment at the time of the disaster was located in an area designated for individual assistance with respect to the disaster;

Amendment Number 18

    Article VII, Distributions, Withdrawals and Forfeitures, Section 7.04, Hardship Withdrawals, subsection (b), Necessary to Satisfy Such Need, is amended effective January 1, 2020, by deleting the following from subsection (1):

    and all nontaxable loans currently available under all plans of the Company and Affiliates, providing that the loan would not itself increase the hardship.

Amendment Number 19

    Article VII, Distributions, Withdrawals and Forfeitures, Section 7.04, Hardship Withdrawals, subsection (b), Necessary to Satisfy Such Need, is amended effective January 1, 2020, by deleting subsection (2) in its entirety and renumbering any section references as applicable.

10

Exhibit 10.1.5.6

IN WITNESS WHEREOF, the undersigned has caused this instrument to be executed on this 24th day of December 2020.

/s/ Nancy Shannon

Nancy Shannon

Vice President of Human Resources of

Consolidated Edison Company of New York, Inc.

And the Plan Administrator of the Thrift Savings Plan

11

EX-10.1.9

Exhibit 10.1.9

DESCRIPTION OF DIRECTORS’ COMPENSATION

    The following tables show, effective as of December 31, 2020, the annual retainer amounts and committee meeting fees payable, in quarterly installments, to the members of the Board of Directors of Consolidated Edison, Inc. (the “Company”) who were not employees of the Company or its subsidiaries:

	Amount
Annual Retainer	$    115,000
Non-executive Chairman Retainer(1)	$    160,000
Lead Director Retainer	$    35,000
Chair of Audit Committee Retainer	$    30,000
Member of Audit Committee Retainer (excluding the Audit Committee Chair)	$    15,000
Chair of the Corporate Governance and Nominating Committee Retainer	$    15,000
Chair of the Finance Committee Retainer	$    15,000
Chair of the Management Development and Compensation Committee Retainer(2)	$    20,000
Retainers for each of the Co-Chairs of the Safety, Environment, Operations and Sustainability Committee(3)	$    7,500
Acting Committee Chair Fee (where the regular Chair is absent)	$    200
Annual equity award (deferred stock units)	$    150,000

Footnotes:

(1)    Effective December 29, 2020.

(2)    Effective April 1, 2020, the annual retainer for the Chair of the Management Development and Compensation Committee was increased from $15,000 to $20,000.

(3)    Effective January 1, 2021, a single Chair of the Safety, Environment, Operations and Sustainability Committee was appointed. As a result, Co-Chair retainers of $7,500 were provided until December 31, 2020 and the annual retainer for the single Chair of the Safety, Environment, Operations and Sustainability Committee became $15,000 as of January 1, 2021.

Non-employee Directors participate in the Company’s Long Term Incentive Plan (the “LTIP”). Pursuant to the LTIP, each non-employee Director then serving is allocated an annual equity award of $150,000 of deferred stock units on the first business day following the Annual Meeting. If a non-employee Director is first appointed to the Board after an annual meeting, his or her first annual equity award is prorated.

Settlement of the annual equity awards of stock units are automatically deferred until the Director’s termination of service from the Board of Directors. Each non-employee Director may elect to receive some or all of his or her annual equity awards of stock units on another date or to further defer any other prior annual equity award of stock units, including any related dividend equivalents earned on such prior annual equity awards of stock units.

Each non-employee Director may also elect to defer all or a portion of his or her retainers into additional deferred stock units, which are deferred until the Director’s termination of service.

Dividend equivalents are payable on deferred stock units in the amount and at the time that dividends are paid on Company Common Stock and are credited in the form of additional deferred stock units which are fully vested as of the date the dividends would have been paid to the Director or, at the Director’s option, are paid in cash.

Exhibit 10.1.9

All payments on account of deferred stock units are made in shares of Company Common Stock. The LTIP provides that cash compensation deferred into stock units, annual equity awards, and dividend equivalents granted to non-employee Directors that are credited in the form of additional deferred stock units, are fully vested, and payable in a single one-time payment of whole shares (rounded to the nearest whole share) within sixty days following separation from Board service unless the Director elected to defer distribution to another date.

The Company reimburses non-employee Directors for reasonable expenses incurred in attending Board and Committee meetings. No person who serves on both the Company’s Board and on the Board of its subsidiary, Consolidated Edison Company of New York, Inc., and corresponding Committees, is paid additional compensation for concurrent service. Directors who are employees of the Company or its subsidiaries do not receive retainers or annual equity awards of deferred stock units for their service on the Board.

Members of the Board are also eligible to participate in the Company’s Stock Purchase Plan (“Stock Purchase Plan”).

Copies of the LTIP and the Company’s Stock Purchase Plan, and amendments thereto, have been (or, as to amendments that may be adopted after the date of this description, will be) included as exhibits to the Company’s Annual Report on Form 10-K or Quarterly Reports on Form 10-Q.

EX-10.1.15.1

Exhibit 10.1.15.1

FIRST AMENDMENT TO CREDIT AGREEMENT

FIRST AMENDMENT TO CREDIT AGREEMENT (this “Amendment”) dated as of January 29, 2021 relating to the Credit Agreement (as extended, amended, supplemented or otherwise modified prior to the date hereof, the “Existing Credit Agreement”), dated as of February 11, 2019, among Consolidated Edison, Inc., as Borrower (“Borrower”), the Lenders from time to time party thereto and Mizuho Bank, Ltd., as Administrative Agent (in such capacity, the “Administrative Agent”) (the Existing Credit Agreement as amended hereby and as further amended, supplemented or otherwise modified from time to time, the “Credit Agreement”).

1.Defined Terms. Unless otherwise specifically defined herein, each term used herein that is defined in the Credit Agreement has the meaning assigned to such term in the Credit Agreement.

2.Amendments. The undersigned lenders, constituting all of the Lenders immediately prior to the Amendment Effective Date (as defined below), consent to amend the Existing Credit Agreement as follows:

f.The following defined term is added to Section 1.01 of the Existing Credit Agreement in the appropriate alphabetical order:

[OMITTED]

f.The definition of “Euro-Dollar Margin” in Section 1.01 of the Existing Credit Agreement is hereby amended and restated in its entirety as follows:

[OMITTED]

g.The definition of “Maturity Date” in Section 1.01 of the Existing Credit Agreement is hereby amended and restated in its entirety as follows:

“Maturity Date” means June 30, 2021, or if such date is not a Domestic Business Day, the immediately preceding Domestic Business Day.

h.The first sentence of Section 2.06(a) of the Existing Credit Agreement is hereby amended and restated in its entirety as follows:

Each Base Rate Loan shall bear interest on the outstanding principal amount thereof, for each day from the date such Loan is made until it becomes due, at a rate per annum equal to the sum of the Base Rate Margin for such day plus the Base Rate for such day.

3.Representations and Warranties. The Borrower hereby represents and warrants to the Administrative Agent that the execution, delivery and performance by the Borrower of this Amendment is within its corporate powers, have been duly authorized by all necessary corporate action and do not contravene, or constitute a default under, any provision of applicable law or

Exhibit 10.1.15.1

regulation or of its certificate of incorporation or by-laws or of any agreement, judgment, injunction, order, decree or other instrument binding upon the Borrower.

4.Conditions Precedent to the Effectiveness of this Amendment. This Amendment shall become effective as of the date when, and only when, the following conditions precedent have been satisfied (such date, the “Amendment Effective Date”):

f.the Administrative Agent shall have received counterparts of this Amendment duly executed by (A) the Borrower and (B) each Lender party hereto;

g.the Borrower shall have paid to the Administrative Agent, for the account of each Lender, all documented fees due and payable to the Lenders (including pursuant to that certain Structuring Fee Letter, dated as of the date hereof, by and among the Borrower and Mizuho) on the Amendment Effective Date;

h.the Administrative Agent shall have received all reasonable and documented out-of-pocket expenses to be paid or reimbursed to the Administrative Agent on the Amendment Effective Date (including, for the avoidance of doubt, legal fees of Davis Polk & Wardwell LLP) that have been invoiced at least three business days prior to the Amendment Effective Date;

i.prior to and immediately after giving effect to this Amendment on the Amendment Effective Date, the representations and warranties in Section 3 of this Amendment shall be true and correct in all material respects; and

j.prior to and immediately after giving effect to this Amendment on the Amendment Effective Date, (i) no Event of Default or Default shall have occurred and be continuing and (ii) the representations and warranties of the Borrower contained in Article 4 of the Credit Agreement shall be true on and as of the Amendment Effective Date, except in the case of any such representation or warranty that expressly relates to a prior date, in which case such representation or warranty shall be true as of such prior date.

5.Governing Law; Submission to Jurisdiction.  This Amendment shall be governed by and construed in accordance with the laws of the State of New York.  The Borrower hereby submits to the exclusive jurisdiction of the United States District Court for the Southern District of New York or, if that court does not have subject matter jurisdiction, of any State court located in the City and County of New York and any appellate court thereof for purposes of all legal proceedings arising out of or relating to this Amendment or the transactions contemplated hereby.  The Borrower irrevocably waives, to the fullest extent permitted by law, any objection which it may now or hereafter have to the laying of the venue of any such proceeding brought in such a court and any claim that any such proceeding brought in such a court has been brought in an inconvenient forum.

6.Counterparts; Integration.  This Amendment may be executed in counterparts (and by different parties hereto in different counterparts), each of which shall constitute an original,

-2-

Exhibit 10.1.15.1

but all of which when taken together shall constitute a single contract.  This Amendment, the Credit Agreement, the Notes, and any separate letter agreements with respect to fees payable to the Administrative Agent or the Lenders, constitute the entire contract among the parties relating to the subject matter hereof and supersede any and all previous agreements and understandings, oral or written, relating to the subject matter hereof. 

7.WAIVER OF JURY TRIAL.  EACH PARTY HERETO HEREBY IRREVOCABLY WAIVES ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THIS AMENDMENT OR THE TRANSACTIONS CONTEMPLATED HEREBY.

8.Incorporation; Execution. The provisions of this Amendment are deemed incorporated into the Credit Agreement as if fully set forth therein. The execution, delivery and effectiveness of this Amendment shall not, except as expressly provided herein, operate as a waiver of any right, power or remedy of any Lender or the Administrative Agent under the Existing Credit Agreement, nor constitute a waiver of any provision of the Existing Credit Agreement.

9.Ratification. The Existing Credit Agreement, as specifically amended by this Amendment, is and shall continue to be in full force and effect and is hereby in all respects ratified and confirmed.

10.Reference. On and after the Amendment Effective Date, each reference in the Credit Agreement to “this Agreement,” “hereunder,” “hereof” or words of like import referring to the Credit Agreement shall mean and be a reference to the Existing Credit Agreement, as amended by this Amendment.

[The remainder of this page is intentionally left blank; signature pages follow]

-3-

CONSOLIDATED EDISON, INC., as Borrower

By:/s/Yukari Saegusa

Name: Yukari Saegusa

Title: Vice President and Treasurer

Exhibit 10.1.15.1

MIZUHO BANK, LTD., as Administrative

Agent and Lender

By:/s/Edward Sacks

Name: Edward Sacks

Title: Executive Director

Bank of America, N.A., as a Lender

By:/s/Jennifer Cochrane

Name: Jennifer Cochrane

Title: Vice President

Exhibit 10.1.15.1

KeyBank National Association, as a Lender

By:/s/Richard Gerling

Name: Richard Gerling

Title: Senior Vice President

Exhibit 10.1.15.1

MUFG Bank, Ltd., as a Lender

By:/s/Nicholas Battista

Name: Nicholas Battista

Title: Managing Director

Exhibit 10.1.15.1

Sumitomo Mitsui Banking Corporation, as a Lender

By:/s/Katie Lee

Name: Katie Lee

Title: Director

EX-23.1

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in the Registration Statements on Form S-3 (No. 333-241717, 333-226538) and Form S-8 (No. 333-197947, 333-108903, 333-190320) of Consolidated Edison, Inc. of our report dated February 18, 2021 relating to the financial statements, financial statement schedulesand the effectiveness of internal control over financial reporting, which appears in this Form 10‑K.

/s/ PricewaterhouseCoopers LLP

New York, New York

February 18, 2021

EX-31.1.1

Exhibit 31.1.1

CERTIFICATIONS

I, Timothy P. Cawley, certify that:

1.I have reviewed this Annual Report on Form 10-K for the year ended December 31, 2020 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: February 18, 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 Annual Report on Form 10-K for the year ended December 31, 2020 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: February 18, 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 Annual Report on Form 10-K for the year ended December 31, 2020, which this statement accompanies, (the “Form 10-K”) 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-K fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Timothy P. Cawley

Timothy P. Cawley

Dated: February 18, 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 Annual Report on Form 10-K for the year ended December 31, 2020, which this statement accompanies, (the “Form 10-K”) 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-K fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Robert Hoglund

Robert Hoglund

Dated: February 18, 2021

EX-3.2.2

Exhibit 3.2.2

BY-LAWS

OF

CONSOLIDATED EDISON COMPANY

OF NEW YORK, INC.

Effective as of December 29, 2020

Exhibit 3.2.2

BY-LAWS

OF

CONSOLIDATED EDISON COMPANY

OF NEW YORK, INC.

Effective as of December 29, 2020

SECTION 1. The annual meeting of stockholders of the Company for the election of Trustees and such other business as may properly come before such meeting shall be held on the third Monday in May in each year at such hour and at such place in the City of New York or the County of Westchester as may be designated by the Board of Trustees.	Date Annual Meeting
SECTION 2. Special meetings of the stockholders of the Company may be held upon call of the Chairman of the Board, the President, the Board of Trustees, or stockholders holding one-fourth of the outstanding shares of stock entitled to vote at such meeting	Special Meetings Stockholders
SECTION 3. Notice of the time and place of every meeting of stockholders, the purpose of such meeting and, in case of a special meeting, the person or persons by or at whose direction the meeting is being called, shall be mailed by the Secretary, or other officer performing his duties, at least ten days, but not more than fifty days, before the meeting to each stockholder of record, at his last known Post Office address; provided, however, that if a stockholder be present at a meeting, in person or by proxy, without protesting prior to the conclusion of the meeting the lack of notice of such meeting, or in writing waives notice thereof before or after the meeting, the mailing to such stockholder of notice of such meeting is unnecessary.	Notice Stockholders’ Meeting
SECTION 4. The holders of a majority of the outstanding shares of stock of the Company, entitled to vote at a meeting, present in person or by proxy shall constitute a quorum, but less than a quorum shall have power to adjourn.	Quorum Stockholders
SECTION 5. The Chairman of the Board, or in his absence the President, shall preside over all meetings of stockholders. In their absence one of the Vice Presidents shall preside over such meetings. The Secretary of the Board of Trustees shall act as Secretary of such meeting, if present. In his absence, the Chairman of the meeting may appoint any person to act as Secretary of the meeting.	Chairman, Secretary, Stockholders’ Meetings
SECTION 6. At each meeting of stockholders at which votes are to be taken by ballot there shall be at least two and not more than five inspectors of election and of stockholders’ votes, who shall be either designated prior to such meeting by the Board of Trustees or, in the absence of such designation, appointed by the Chairman of the meeting.	Inspectors of Election

1

Exhibit 3.2.2

SECTION 7. The Board of Trustees may, in their discretion, appoint one or more transfer agents, paying agents and/or registrars of the stock of the Company.	Stock Transfers Registrars
SECTION 8. The affairs of the Company shall be managed under the direction of a Board consisting of thirteen Trustees, who shall be elected annually by the stockholders by ballot and shall hold office until their successors are elected and qualified. Vacancies in the Board of Trustees may be filled by the Board at any meeting, but if the number of Trustees is increased or decreased by the Board by an amendment of this section of the By-laws, such amendment shall require the vote of a majority of the whole Board. Members of the Board of Trustees shall be entitled to receive such reasonable fees or other forms of compensation, on a per diem, annual or other basis, as may be fixed by resolution of the Board of Trustees or the stockholders in respect of their services as such, including attendance at meetings of the Board and its committees; provided, however, that nothing herein contained shall be construed as precluding any Trustee from serving the Company in any capacity other than as a member of the Board or a committee thereof and receiving compensation for such other services.	Number of Board Members Vacancies Fees
SECTION 9. Meetings of the Board of Trustees shall be held at the time and place fixed by resolution of the Board or upon call of the Chairman of the Board, the President, or a Vice President or any two Trustees. The Secretary of the Board or officer performing his duties shall give 24 hours’ notice of all meetings of Trustees; provided that a meeting may be held without notice immediately after the annual election of Trustees, and notice need not be given of regular meetings held at times fixed by resolution of the Board. Meetings may be held at any time without notice if all the Trustees are present and none protests the lack of notice either prior to the meeting or at its commencement, or if those not present waive notice either before or after the meeting. Notice by mailing or telegraphing, or delivering by hand, to the usual business address or residence of the Trustee not less than the time above specified before the meeting shall be sufficient. A majority of the Trustees in office shall constitute a quorum, but less than such quorum shall have power to adjourn. The Chairman of the Board or, in his absence a Chairman pro tem elected by the meeting from among the Trustees present shall preside at all meetings of the Board. Any one or more members of the Board may participate in a meeting of the Board by means of a conference telephone or similar communications equipment allowing all persons participating in the meeting to hear each other at the same time. Participation by such means shall constitute presence in person at such meeting. Any action required or permitted to be taken by the Board may be taken without a meeting if all members of the Board consent in writing to the adoption of a resolution authorizing the action; provided, however, that no action taken by the Board by unanimous written consent shall be taken in lieu of a regular monthly meeting of the Board. Each resolution so adopted and the written consents thereto by the members of the Board shall be filed with the minutes of the proceedings of the Board.	Board Meetings Notices Quorum Participation by Conference Telephone Action by Unanimous Written Consent
SECTION 10. The Board of Trustees, as soon as may be practical after the election of Trustees in each year, shall elect from their number a Chairman of the Board and shall elect a President and a Chief Executive Officer of the Company. The Board shall also elect one or more Vice Presidents, a Secretary and a Treasurer, and may from time to time elect such other officers as they may deem proper. Any two or more offices may be held by the same person, except as otherwise may be required by law.	Election of Officers

2

Exhibit 3.2.2

SECTION 11. The term of office of all officers shall be until the next election of Trustees and until their respective successors are chosen and qualify, but any officer may be removed from office at any time by the Board of Trustees. Vacancies among the officers may be filled by the Board of Trustees at any meeting.	Term of Office Vacancies
SECTION 12. The Chairman of the Board and the President shall have such duties as usually pertain to their respective offices, except as otherwise directed by the Board of Trustees or the Executive Committee, and shall also have such powers and duties as may from time to time be conferred upon them by the Board of Trustees or the Executive Committee. The Vice Presidents and the other officers of the Company shall have such duties as usually pertain to their respective offices, except as otherwise directed by the Board of Trustees, the Executive Committee, the Chairman of the Board or the President, and shall also have such powers and duties as may from time to time be conferred upon them by the Board of Trustees, the Executive Committee, the Chairman of the Board or the President.	Duties of Executive Officers Duties of Other Officers
SECTION 13. The Board of Trustees, as soon as may be after the election of Trustees in each year, may by a resolution passed by a majority of the whole Board, appoint an Executive Committee, to consist of the Chairman of the Board and three or more additional Trustees as the Board may from time to time determine, which shall have and may exercise during the intervals between the meetings of the Board all the powers vested in the Board except that neither the Executive Committee nor any other committee appointed pursuant to this section of the By-laws shall have authority as to any of the following matters: the submission to stockholders of any action as to which stockholders’ authorization is required by law; the filling of vacancies on the Board or on any committee thereof; the fixing of compensation of any Trustee for serving on the Board or on any committee thereof; the amendment or repeal of these By-laws, or the adoption of new By-laws; and the amendment or repeal of any resolution of the Board which by its terms shall not be so amendable or repealable. The Board shall have the power at any time to change the membership of such Executive Committee and to fill vacancies in it. The Executive Committee may make rules for the conduct of its business and may appoint such committees and assistants as it may deem necessary. Four members of said Executive Committee shall constitute a quorum. The Chairman of the Board or, in his absence a Chairman pro tem elected by the meeting from among the members of the Executive Committee present shall preside at all meetings of the Executive Committee. The Board may designate one or more Trustees as alternate members of any committee appointed pursuant to this section of the By-laws who may replace any absent member or members at any meeting of such committee. The Board of Trustees may also from time to time appoint other committees consisting of three or more Trustees with such powers as may be granted to them by the Board of Trustees, subject to the restrictions contained in this section of the By-laws. Any one or more members of any committee appointed pursuant to this section may participate in any meeting of such committee by means of a conference telephone or similar communications equipment allowing all persons participating in the meeting to hear each other at the same time. Participation by such means shall constitute presence in person at such meeting. Any action required or permitted to be taken by any committee appointed pursuant to this section may be taken without a meeting if all members of such committee consent in writing to the adoption of a resolution authorizing the action. Each resolution so adopted and the written consents thereto by the members of such committee shall be filed with the minutes of the proceedings of such committee.	Appointment Executive Committee Executive Committee Quorum Committee Meetings Participation by Conference Telephone Action by Unanimous Written Consent

3

Exhibit 3.2.2

SECTION 14. The Board of Trustees are authorized to select such depositories as they shall deem proper for the funds of the Company. All checks and drafts against such deposited funds shall be signed by such person or persons and in such manner as may be specified by the Board of Trustees.

Depositories Signatures

SECTION 15. The Company shall fully indemnify in all circumstances to the extent not prohibited by law any person made, or threatened to be made, a party to an action or proceeding, whether civil or criminal, including an investigative, administrative or legislative proceeding, and including an action by or in the right of the Company or any other corporation of any type or kind, domestic or foreign, or any partnership, joint venture, trust, employee benefit plan or other enterprise, by reason of the fact that he, his testator or intestate, is or was a Trustee or officer of the Company, or is or was serving at the request of the Company any other corporation of any type or kind, domestic or foreign, or any partnership, joint venture, trust, employee benefit plan or other enterprise, as a director, officer or in any other capacity against any and all judgments, fines, amounts paid in settlement, and expenses, including attorneys’ fees, actually and reasonably incurred as a result of or in connection with any such action or proceeding or related appeal; provided, however, that no indemnification shall be made to or on behalf of any Trustee, director or officer if a judgment or other final adjudication adverse to the Trustee, director or officer establishes that his acts were committed in bad faith or were the result of active and deliberate dishonesty and were material to the cause of action so adjudicated, or that he personally gained in fact a financial profit or other advantage to which he was not legally entitled; and, except in the case of an action or proceeding specifically approved by the Board of Trustees, the Company shall pay expenses incurred by or on behalf of such a person in defending such a civil or criminal action or proceeding (including appeals) in advance of the final disposition of such action or proceeding promptly upon receipt by the Company, from time to time, of a written demand of such person for such advancement, together with an undertaking by or on behalf of such person to repay any expenses so advanced to the extent that the person receiving the advancement is ultimately found not to be entitled to indemnification for such expenses; and the right to indemnification and advancement of defense expenses granted by or pursuant to this by-law (i) shall not limit or exclude, but shall be in addition to, any other rights which may be granted by or pursuant to any statute, certificate of incorporation, by-law, resolution or agreement, (ii) shall be deemed to constitute contractual obligations of the Company to any Trustee, director or officer who serves in such capacity at any time while this by-law is in effect, (iii) are intended to be retroactive and shall be available with respect to events occurring prior to the adoption of this by-law and (iv) shall continue to exist after the repeal or modification hereof with respect to events occurring prior thereto. It is the intent of this by-law to require the Company to indemnify the persons referred to herein for the aforementioned judgments, fines, amounts paid in settlement and expenses, including attorneys’ fees, in each and every circumstance in which such indemnification could lawfully be permitted by an express provision of a by-law, and the indemnification required by this by-law shall not be limited by the absence of an express recital of such circumstances. The Company may, with the approval of the Board of Trustees, enter into an agreement with any person who is, or is about to become, a Trustee or officer of the Company, or who is serving, or is about to serve, at the request of the Company, any other corporation of any type or kind, domestic or foreign, or any partnership, joint venture, trust, employee benefit plan or other enterprise, as a director, officer or in any other capacity, which agreement may provide for indemnification of such person and advancement of defense expenses to such person upon such terms, and to the extent, as may be permitted by law.

Indemnification of Trustees and Officers

4

Exhibit 3.2.2

SECTION 16. Wherever the expression “Trustees” or “Board of Trustees” is used in these By-laws the same shall be deemed to apply to the Directors or Board of Directors, as the case may be, if the designation of those persons constituting the governing board of this Company is changed from “Trustees” to “Directors”.
SECTION 17. Either the Board of Trustees or the stockholders may alter or amend these By-laws at any meeting duly held as above provided, the notice of which includes notice of the proposed amendment.	Amendment of By-laws

5

Exhibit 3.2.2

EMERGENCY BY-LAWS

OF

CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

As Amended

February 19, 2009

Effective February 19, 2009

SECTION 1. These Emergency By-laws may be declared effective by the Defense Council of New York as constituted under the New York State Defense Emergency Act in the event of attack and shall cease to be effective when the Council declares the end of the period of attack. These Emergency By-laws shall also be effective in the event of an attack, major disaster, catastrophe, or national or local emergency, during which a quorum of the entire Board of Trustees is unavailable to act in a meeting of the Board called in the manner provided in the By-laws of the Company.

SECTION 2. During the period in which these Emergency By-laws are effective, the affairs of the Company shall be managed by such Trustees theretofore elected as are available to act, and a majority of such Trustees shall constitute a quorum. In the event that there are less than three Trustees available to act, then and in that event the Board of Trustees shall consist of such Trustees theretofore elected and available to act, if any, plus such number of officers of the Company, added to the Board in the order of seniority by title and, within title, seniority by tenure with the Company, not theretofore elected as Trustees as will make a Board of not less than three nor more than five members. The Board as so constituted shall continue until such time as a quorum of the entire Board (including any duly elected successors) becomes available.

SECTION 3. The By-laws of the Company shall remain in effect during the period in which these Emergency By-laws are effective to the extent that said By-laws are not inconsistent with these Emergency By-laws.

6

EX-23.2

Exhibit 23.2

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in the Registration Statement on Form S-3 (No. 333-226539) of Consolidated Edison Company of New York, Inc. of our report dated February 18, 2021 relating to the financial statements, financial statement scheduleand the effectiveness of internal control over financial reporting, which appears in this Form 10‑K.

/s/ PricewaterhouseCoopers LLP

New York, New York

February 18, 2021

EX-31.2.1

Exhibit 31.2.1

CERTIFICATIONS

I, Timothy P. Cawley, certify that:

1.I have reviewed this Annual Report on Form 10-K for the year ended December 31, 2020 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: February 18, 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 Annual Report on Form 10-K for the year ended December 31, 2020 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: February 18, 2021

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

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 Annual Report on Form 10-K for the year ended December 31, 2020, which this statement accompanies, (the “Form 10-K”) 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-K fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Timothy P. Cawley

Timothy P. Cawley

Dated: February 18, 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 Annual Report on Form 10-K for the year ended December 31, 2020, which this statement accompanies, (the “Form 10-K”) 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-K fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Robert Hoglund

Robert Hoglund

Dated: February 18, 2021

XML

Cover Page - USD ($)
$ in Billions

12 Months Ended

Dec. 31, 2020

Jan. 31, 2021

Jun. 30, 2020

Document Information [Line Items]

Document Type

10-K

Document Annual Report

true

Document Period End Date

Dec. 31, 2020

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 Well-known Seasoned Issuer

Yes

Entity Voluntary Filers

No

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

ICFR Auditor Attestation Flag

true

Entity Shell Company

false

Entity Public Float

$ 24.0

Entity Common Stock, Shares Outstanding

342,419,162

Amendment Flag

false

Document Fiscal Year Focus

2020

Current Fiscal Year End Date

--12-31

Document Fiscal Period Focus

FY

Entity Central Index Key

0001047862

Documents Incorporated by Reference

Documents Incorporated By Reference

Portions of Con Edison’s definitive proxy statement for its Annual Meeting of Stockholders to be held on May 17, 2021, to be filed with the Commission pursuant to Regulation 14A, not later than 120 days after December 31, 2020, is incorporated in Part III of this report.

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 Well-known Seasoned Issuer

Yes

Entity Voluntary Filers

No

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

2020

Current Fiscal Year End Date

--12-31

Document Fiscal Period Focus

FY

Entity Central Index Key

0000023632

XML

Consolidated Income Statement - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
OPERATING REVENUES
Total operating revenues	$ 12,246	$ 12,574	$ 12,337
OPERATING EXPENSES
Depreciation and amortization	1,920	1,684	1,438
Taxes, other than income taxes	2,575	2,406	2,266
TOTAL OPERATING EXPENSES	9,592	9,898	9,804
Gain on acquisition of Sempra Solar Holdings, LLC	0	0	131
OPERATING INCOME	2,654	2,676	2,664
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	(214)	96	119
Other income	23	45	17
Allowance for equity funds used during construction	17	14	12
Other deductions	(227)	(104)	(210)
TOTAL OTHER INCOME (DEDUCTIONS)	(401)	51	(62)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,253	2,727	2,602
INTEREST EXPENSE
Interest on long-term debt	915	888	780
Other interest	118	116	49
Allowance for borrowed funds used during construction	(14)	(13)	(10)
NET INTEREST EXPENSE	1,019	991	819
INCOME BEFORE INCOME TAX EXPENSE	1,234	1,736	1,783
INCOME TAX EXPENSE	90	296	401
NET INCOME	1,144	1,440	1,382
Income attributable to non-controlling interest	43	97	0
NET INCOME FOR COMMON STOCK	$ 1,101	$ 1,343	$ 1,382
Net income per common share — basic (in dollars per share)	$ 3.29	$ 4.09	$ 4.43
Net income per common share — diluted (in dollars per share)	$ 3.28	$ 4.08	$ 4.42
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (in shares)	334.8	328.5	311.7
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (in shares)	335.7	329.5	312.9
CECONY
OPERATING REVENUES
Total operating revenues	$ 10,647	$ 10,821	$ 10,680
OPERATING EXPENSES
Depreciation and amortization	1,598	1,373	1,276
Taxes, other than income taxes	2,456	2,295	2,156
TOTAL OPERATING EXPENSES	8,337	8,473	8,326
OPERATING INCOME	2,310	2,348	2,354
OTHER INCOME (DEDUCTIONS)
Investment income (loss)	19	40	13
Allowance for equity funds used during construction	14	12	11
Other deductions	(204)	(87)	(167)
TOTAL OTHER INCOME (DEDUCTIONS)	(171)	(35)	(143)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,139	2,313	2,211
INTEREST EXPENSE
Interest on long-term debt	718	672	662
Other interest	33	67	36
Allowance for borrowed funds used during construction	(12)	(11)	(9)
NET INTEREST EXPENSE	739	728	689
INCOME BEFORE INCOME TAX EXPENSE	1,400	1,585	1,522
INCOME TAX EXPENSE	215	335	326
NET INCOME FOR COMMON STOCK	1,185	1,250	1,196
Electric
OPERATING REVENUES
Total operating revenues	8,730	8,694	8,612
Electric | CECONY
OPERATING REVENUES
Total operating revenues	8,103	8,062	7,971
Gas
OPERATING REVENUES
Total operating revenues	2,269	2,391	2,327
OPERATING EXPENSES
Operating costs	527	880	1,041
Gas | CECONY
OPERATING REVENUES
Total operating revenues	2,036	2,132	2,078
OPERATING EXPENSES
Operating costs	426	606	643
Steam
OPERATING REVENUES
Total operating revenues	508	627	631
Steam | CECONY
OPERATING REVENUES
Total operating revenues	508	627	631
Non-utility
OPERATING REVENUES
Total operating revenues	739	862	767
Purchased power
OPERATING EXPENSES
Operating costs	1,600	1,546	1,644
Purchased power | CECONY
OPERATING EXPENSES
Operating costs	1,432	1,357	1,433
Fuel
OPERATING EXPENSES
Operating costs	156	207	263
Fuel | CECONY
OPERATING EXPENSES
Operating costs	156	207	263
Other operations and maintenance
OPERATING EXPENSES
Operating costs	2,814	3,175	3,152
Other operations and maintenance | CECONY
OPERATING EXPENSES
Operating costs	$ 2,269	$ 2,635	$ 2,555

XML

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Net income	$ 1,101	$ 1,343	$ 1,382
Net Income	1,144	1,440	1,382
INCOME ATTRIBUTABLE TO NON-CONTROLLING INTEREST	(43)	(97)	0
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	(6)	(5)	10
Other income, net of taxes	0	2	0
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
COMPREHENSIVE INCOME	1,095	1,340	1,392
CECONY
Net income	1,185	1,250	1,196
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	(1)	(3)	1
Other income, net of taxes	0	2	0
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	1
COMPREHENSIVE INCOME	$ 1,184	$ 1,249	$ 1,197

XML

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
OPERATING ACTIVITIES
Net Income	$ 1,144	$ 1,440	$ 1,382
Net income	1,101	1,343	1,382
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,920	1,684	1,438
Impairment of assets	320	0	0
Deferred income taxes	85	308	408
Rate case amortization and accruals	(40)	(116)	(117)
Common equity component of allowance for funds used during construction	(17)	(14)	(12)
Net derivative (gains)/losses	57	27	8
(Gain) on Sale of Assets	0	(14)	0
Unbilled revenue and net unbilled revenue deferrals	(1)	(3)	18
(Gain) on existing project interests due to acquisition of Sempra Solar Holdings, LLC	0	0	(131)
Other non-cash items, net	127	(18)	115
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(543)	23	(140)
Materials and supplies, including fuel oil and gas in storage	(4)	6	(20)
Revenue decoupling mechanism receivable	(61)	(76)	0
Other receivables and other current assets	(134)	54	(62)
Taxes receivable	(6)	29	27
Prepayments	(11)	(73)	(7)
Accounts payable	170	10	(46)
Pensions and retiree benefits obligations, net	285	357	325
Pensions and retiree benefits contributions	(478)	(357)	(479)
Accrued taxes	74	10	(49)
Accrued interest	(4)	24	(35)
Superfund and environmental remediation costs, net	(22)	(9)	(19)
Distributions from equity investments	39	57	107
System benefit charge	(119)	20	92
Deferred charges, noncurrent assets and other regulatory assets	(653)	(492)	(393)
Deferred credits and other regulatory liabilities	10	278	436
Other current and noncurrent liabilities	60	(21)	(151)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,198	3,134	2,695
INVESTING ACTIVITIES
Utility construction expenditures	(3,326)	(3,238)	(3,251)
Cost of removal less salvage	(310)	(295)	(258)
Non-utility construction expenditures	(583)	(248)	(246)
Acquisition of Sempra Solar Holdings, LLC, net of cash acquired	0	0	(1,488)
Proceeds from sale of assets	0	192	5
Other investing activities	22	22	34
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,224)	(3,782)	(5,471)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	178	(874)	1,989
Issuance of long-term debt	2,925	3,017	3,030
Retirement of long-term debt	(518)	(1,195)	(1,938)
Debt issuance costs	(47)	(32)	(61)
Common stock dividends	(975)	(924)	(842)
Issuance of common shares - public offering	640	825	705
Issuance of common shares for stock plans	58	54	53
Distribution to noncontrolling interest	(16)	(12)	2
NET CASH FLOWS FROM FINANCING ACTIVITIES	2,245	859	2,938
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	219	211	162
BALANCE AT BEGINNING OF PERIOD	1,217	1,006	844
BALANCE AT END OF PERIOD	1,436	1,217	1,006
Cash paid/(received) during the period for:
Interest	920	876	805
Income taxes	38	(26)	0
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	478	336	369
Issuance of common shares for dividend reinvestment	48	47	47
Debt assumed with business acquisitions	0	0	568
Electric and Gas Transmission Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(3)	(205)	(248)
Renewable Electric Production Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(24)	(10)	(19)
CECONY
OPERATING ACTIVITIES
Net income	1,185	1,250	1,196
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,598	1,373	1,276
Deferred income taxes	168	128	354
Rate case amortization and accruals	(40)	(117)	(133)
Common equity component of allowance for funds used during construction	(14)	(12)	(11)
(Gain) on Sale of Assets	0	(14)	0
Unbilled revenue and net unbilled revenue deferrals	(47)	(3)	(4)
Other non-cash items, net	66	7	13
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(516)	3	(153)
Materials and supplies, including fuel oil and gas in storage	2	11	(17)
Revenue decoupling mechanism receivable	(53)	(76)	0
Other receivables and other current assets	(49)	54	(96)
Accounts receivables from affiliated companies	(61)	141	(150)
Prepayments	19	(61)	(9)
Accounts payable	145	(7)	(27)
Accounts payable to affiliated companies	9	(4)	7
Pensions and retiree benefits obligations, net	253	330	293
Pensions and retiree benefits contributions	(438)	(325)	(440)
Accrued taxes	61	11	(47)
Accrued taxes to affiliated companies	1	0	(72)
Accrued interest	13	1	(1)
Superfund and environmental remediation costs, net	(30)	(12)	(18)
System benefit charge	(112)	18	86
Deferred charges, noncurrent assets and other regulatory assets	(603)	(486)	(314)
Deferred credits and other regulatory liabilities	92	306	549
Other current and noncurrent liabilities	44	(14)	(78)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,693	2,502	2,204
INVESTING ACTIVITIES
Utility construction expenditures	(3,112)	(3,028)	(3,051)
Cost of removal less salvage	(304)	(288)	(255)
Proceeds from sale of assets	0	192	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,416)	(3,124)	(3,306)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	523	(55)	1,042
Issuance of long-term debt	2,200	1,300	2,740
Retirement of long-term debt	(350)	(475)	(1,836)
Debt issuance costs	(34)	(21)	(30)
Capital contribution by parent	500	900	120
Dividend to parent	(982)	(912)	(846)
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,857	737	1,190
CASH, TEMPORARY CASH INVESTMENTS AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	134	115	88
BALANCE AT BEGINNING OF PERIOD	933	818	730
BALANCE AT END OF PERIOD	1,067	933	818
Cash paid/(received) during the period for:
Interest	693	676	662
Income taxes	102	73	195
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	417	285	299
Software Licenses
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	51	80	100
Software Licenses | CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	48	76	95
Equipment
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	28	33	0
Equipment | CECONY
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Capital expenditures incurred but unpaid as of end of period	$ 28	$ 33	$ 0

XML

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
CURRENT ASSETS
Cash and temporary cash investments	$ 1,272	$ 981
Accounts receivable - customers, less allowance for uncollectible accounts	1,701	1,236
Other receivables, less allowance for uncollectible accounts	278	184
Taxes receivable	26	20
Accrued unbilled revenue	599	599
Fuel oil, gas in storage, materials and supplies, at average cost	356	352
Prepayments	271	260
Regulatory assets	266	128
Restricted cash	164	236
Revenue decoupling mechanism receivable	137	76
Other current assets	231	200
TOTAL CURRENT ASSETS	5,301	4,272
INVESTMENTS	1,816	2,065
UTILITY PLANT, AT ORIGINAL COST
General	3,880	3,562
TOTAL	50,738	48,136
Less: Accumulated depreciation	11,188	10,322
Net	39,550	37,814
Construction work in progress	2,474	1,937
NET UTILITY PLANT	42,024	39,751
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	3,893	3,829
Construction work in progress	638	309
NET PLANT	46,555	43,889
OTHER NONCURRENT ASSETS
Goodwill	446	446
Intangible assets, less accumulated amortization of $228 and $126 in 2020 and 2019, respectively	1,460	1,557
Operating lease right-of-use-asset	837
Regulatory assets	6,195	4,859
Other deferred charges and noncurrent assets	285	134
TOTAL OTHER NONCURRENT ASSETS	9,223	7,853
TOTAL ASSETS	62,895	58,079
CURRENT LIABILITIES
Long-term debt due within one year	1,967	1,446
Term Loan	165	0
Notes payable	1,705	1,692
Accounts payable	1,475	1,164
Customer deposits	311	346
Accrued taxes	150	76
Accrued interest	149	153
Accrued wages	108	102
Fair value of derivative liabilities	238	123
Regulatory liabilities	36	102
System benefit charge	528	647
Operating lease liabilities	96	65
Other current liabilities	426	371
TOTAL CURRENT LIABILITIES	7,354	6,287
NONCURRENT LIABILITIES
Provision for injuries and damages	178	130
Pensions and retiree benefits	2,257	1,516
Superfund and other environmental costs	857	734
Asset retirement obligations	576	425
Fair value of derivative liabilities	240	105
Deferred income taxes and unamortized investment tax credits	6,475	6,227
Operating lease liabilities	764	809
Regulatory liabilities	4,513	4,827
Other deferred credits and noncurrent liabilities	234	279
TOTAL NONCURRENT LIABILITIES	16,094	15,052
LONG-TERM DEBT	20,382	18,527
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	18,847	18,022
Noncontrolling interest	218	191
TOTAL EQUITY (See Statement of Equity)	19,065	18,213
TOTAL LIABILITIES AND EQUITY	62,895	58,079
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	33,315	31,866
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	10,847	10,107
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,696	2,601
CECONY
CURRENT ASSETS
Cash and temporary cash investments	1,067	933
Accounts receivable - customers, less allowance for uncollectible accounts	1,595	1,153
Other receivables, less allowance for uncollectible accounts	134	120
Taxes receivable	8	0
Accrued unbilled revenue	523	477
Accounts receivable from affiliated companies	134	73
Fuel oil, gas in storage, materials and supplies, at average cost	291	293
Prepayments	159	178
Regulatory assets	244	113
Revenue decoupling mechanism receivable	129	76
Other current assets	123	127
TOTAL CURRENT ASSETS	4,407	3,543
INVESTMENTS	541	461
UTILITY PLANT, AT ORIGINAL COST
General	3,585	3,271
TOTAL	47,529	45,090
Less: Accumulated depreciation	10,297	9,490
Net	37,232	35,600
Construction work in progress	2,320	1,812
NET UTILITY PLANT	39,552	37,412
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	2	2
NET PLANT	39,554	37,414
OTHER NONCURRENT ASSETS
Goodwill	245	245
Operating lease right-of-use-asset	578	601
Regulatory assets	5,745	4,487
Other deferred charges and noncurrent assets	142	51
TOTAL OTHER NONCURRENT ASSETS	6,465	5,139
TOTAL ASSETS	50,967	46,557
CURRENT LIABILITIES
Long-term debt due within one year	640	350
Notes payable	1,660	1,137
Accounts payable	1,232	956
Customer deposits	296	334
Accounts payable to affiliated companies	22	13
Accrued taxes	132	71
Accrued taxes to affiliated companies	1	0
Accrued interest	126	113
Accrued wages	97	92
Fair value of derivative liabilities	163	81
Regulatory liabilities	11	63
System benefit charge	475	587
Operating lease liabilities	73	54
Other current liabilities	319	280
TOTAL CURRENT LIABILITIES	5,247	4,131
NONCURRENT LIABILITIES
Provision for injuries and damages	172	125
Pensions and retiree benefits	1,943	1,241
Superfund and other environmental costs	780	654
Asset retirement obligations	508	362
Fair value of derivative liabilities	105	65
Deferred income taxes and unamortized investment tax credits	6,411	6,000
Operating lease liabilities	512	551
Regulatory liabilities	4,094	4,427
Other deferred credits and noncurrent liabilities	197	240
TOTAL NONCURRENT LIABILITIES	14,722	13,665
LONG-TERM DEBT	16,149	14,614
COMMITMENTS, CONTINGENCIES, AND GUARANTEES (Note B, Note G, and Note H)
EQUITY
Common shareholders’ equity	14,849	14,147
TOTAL LIABILITIES AND EQUITY	50,967	46,557
CECONY | Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	31,327	29,989
CECONY | Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	9,921	9,229
CECONY | Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,696	$ 2,601

XML

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Accounts receivable - customers, allowance for uncollectible accounts	$ 148	$ 70
Other receivables, allowance for uncollectible accounts	7	4
Non-utility property, accumulated depreciation	522	391
Intangible assets, accumulated amortization	228	126
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	138	65
Other receivables, allowance for uncollectible accounts	4	3
Non-utility property, accumulated depreciation	$ 25	$ 25

XML

Consolidated Statement of Equity - USD ($) $ in Millions	Total	Common Stock	Additional Paid-In Capital	Retained Earnings	Treasury Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Noncontrolling 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)
BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2017		310,000,000								235,000,000
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2017	$ 15,425	$ 34	$ 6,298	$ 10,235	$ (1,038)	$ (85)	$ (26)	$ 7
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2017									$ 12,439	$ 589	$ 4,649	$ 8,231	$ (962)	$ (62)	$ (6)
TREASURY STOCK, BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2017					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,382								1,196			1,196
Net Income	1,382			1,382
Common stock dividends	(889)			(889)					(846)			(846)
Issuance of common shares - public offering (in shares)		11,000,000
Issuance of common shares - public offering	705		719			(14)
Issuance of common shares for stock plans	100		100
Capital contribution by parent									120		120
Other comprehensive income	10						10		1						1
Noncontrolling interest	106							106
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2018		321,000,000								235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2018	16,839	$ 34	7,117	10,728	$ (1,038)	(99)	(16)	113
BALANCE AS OF END OF PERIOD at Dec. 31, 2018									12,910	$ 589	4,769	8,581	(962)	(62)	(5)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2018					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,343								1,250			1,250
Net Income	1,440			1,343				97
Common stock dividends	(971)			(971)					(912)			(912)
Issuance of common shares - public offering (in shares)		12,000,000
Issuance of common shares - public offering	825	$ 1	835			(11)
Issuance of common shares for stock plans	102		102
Capital contribution by parent									900		900
Other comprehensive income	(3)						(3)		$ (1)						(1)
Noncontrolling interest	$ (19)							(19)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2019	332,629,597	333,000,000							235,488,094	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2019	$ 18,213	$ 35	8,054	11,100	$ (1,038)	(110)	(19)	191
BALANCE AS OF END OF PERIOD at Dec. 31, 2019	18,022								$ 14,147	$ 589	5,669	8,919	(962)	(62)	(6)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2019					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,101								1,185			1,185
Net Income	1,144			1,101				43
Common stock dividends	(1,023)			(1,023)					(982)			(982)
Issuance of common shares - public offering (in shares)		9,000,000
Issuance of common shares - public offering	640	$ 1	641			(2)
Issuance of common shares for stock plans	113		113
Capital contribution by parent									500		500
Other comprehensive income	(6)						(6)		$ (1)						(1)
Noncontrolling interest	$ (16)							(16)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020	342,297,534	342,000,000							235,488,094	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2020	$ 19,065	$ 36	$ 8,808	$ 11,178	$ (1,038)	$ (112)	$ (25)	$ 218
BALANCE AS OF END OF PERIOD at Dec. 31, 2020	$ 18,847								$ 14,849	$ 589	$ 6,169	$ 9,122	$ (962)	$ (62)	$ (7)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2020					23,000,000

XML

Consolidated Statement of Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Statement of Stockholders' Equity [Abstract]
Common stock dividends per share (in dollars per share)	$ 3.06	$ 2.96	$ 2.86

XML

Consolidated Statement of Capitalization - USD ($) shares in Millions, $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Schedule of Capitalization, Equity [Line Items]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	342	333
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 18,872	$ 18,041
Pension plan liability adjustments, net of taxes	(23)	(17)
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes	(2)	(2)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(25)	(19)
Equity	18,847	18,022
Noncontrolling interest	218	191
TOTAL EQUITY (See Statement of Equity)	$ 19,065	$ 18,213
CECONY
Schedule of Capitalization, Equity [Line Items]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	235	235
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	$ 14,856	$ 14,153
Pension plan liability adjustments, net of taxes	(5)	0
Unrealized gains/(losses) on derivatives qualified as cash flow hedges, less reclassification adjustment for gains/(losses) included in net income and reclassification adjustment for unrealized losses included in regulatory assets, net of taxes	(2)	(6)
TOTAL ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(7)	(6)
Equity	14,849	14,147
TOTAL SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	$ 14,849	$ 14,147

XML

Consolidated Statement of Capitalization - Long-term Debt - USD ($) $ in Millions		Dec. 31, 2020	Dec. 31, 2019
Schedule of Capitalization, Long-term Debt [Line Items]
Other long-term debt		$ 971	$ 974
Unamortized debt expense		(168)	(141)
Unamortized debt discount		(47)	(37)
TOTAL		22,349	19,973
Less: Long-term debt due within one year			1,446
TOTAL LONG-TERM DEBT		20,382	18,527
TOTAL CAPITALIZATION		39,229	36,549
CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Unamortized debt expense		(130)	(115)
Unamortized debt discount		(46)	(36)
TOTAL		16,789	14,964
Less: Long-term debt due within one year			350
TOTAL LONG-TERM DEBT		16,149	14,614
TOTAL CAPITALIZATION		$ 30,998	28,761
Copper Mountain Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.04%
TOTAL PROJECT DEBT	[1]	$ 204	224
Coram
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT	[1]	$ 141	150
Coram | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.78%
Coram | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.52%
Copper Mountain Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.10%
TOTAL PROJECT DEBT	[1]	$ 264	289
CED Southwest
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.72%
TOTAL PROJECT DEBT	[1]	$ 437	456
Wind Holdings
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.41%
TOTAL PROJECT DEBT		$ 109	123
Copper Mountain Solar 1
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.41%
TOTAL PROJECT DEBT	[1]	$ 56	67
Mesquite Solar 1
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 180	193
Mesquite Solar 1 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.24%
Mesquite Solar 1 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.03%
Texas Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		$ 54	56
Texas Solar 4 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
Texas Solar 4 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.95%
California Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.94%
TOTAL PROJECT DEBT		$ 93	98
California Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.07%
TOTAL PROJECT DEBT		$ 82	86
California Solar
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.78%
TOTAL PROJECT DEBT		$ 178	184
California Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.82%
TOTAL PROJECT DEBT		$ 284	297
Broken Bow II
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.82%
TOTAL PROJECT DEBT		$ 67	68
Texas Solar 5
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.53%
TOTAL PROJECT DEBT		$ 140	145
Texas Solar 7
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.21%
TOTAL PROJECT DEBT		$ 192	199
Upton County Solar
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL PROJECT DEBT		$ 87	90
Other project debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		10	12
Project Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		2,578	2,737
Debentures
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		18,565	15,990
Debentures | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 16,515	14,665
Debentures | Debenture Series 2010A, 4.45% Due 2020
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 0	350
Debentures | Debenture Series 2010A, 4.45% Due 2020 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 0	350
Debentures | Debenture Series 2016A, 2.00% Due 2021
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.00%
TOTAL		$ 500	500
Debentures | Debenture 2018C, 0.65 Percent, Due 2021
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.65%
TOTAL		$ 640	640
Debentures | Debenture 2020A, 0.65 Percent, Due 2023
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.65%
TOTAL	[2]	$ 650	0
Debentures | Debenture 2014B, 3.30 Percent, Due 2024
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.30%
TOTAL		$ 250	250
Debentures | Debenture 2014B, 3.30 Percent, Due 2024 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.30%
TOTAL		$ 250	250
Debentures | Debenture Series 2016B, 2.90% Due 2026
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.90%
TOTAL		$ 250	250
Debentures | Debenture Series 2016B, 2.90% Due 2026 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.90%
TOTAL		$ 250	250
Debentures | Debenture Series 1997F, 6.50% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.50%
TOTAL		$ 80	80
Debentures | Debenture Series 2017B, 3.125% Due 2027
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.125%
TOTAL		$ 350	350
Debentures | Debenture Series 2017B, 3.125% Due 2027 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.125%
TOTAL		$ 350	350
Debentures | Debenture Series 2018A, 3.80% Due 2028
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.80%
TOTAL		$ 300	300
Debentures | Debenture Series 2018A, 3.80% Due 2028 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.80%
TOTAL		$ 300	300
Debentures | Debenture Series 2018D, 4.00% Due 2028
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
TOTAL		$ 500	500
Debentures | Debenture Series 2018D, 4.00% Due 2028 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
TOTAL		$ 500	500
Debentures | Debenture 2019B, 2.94 Percent, Due 2029
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.94%
TOTAL		$ 44	44
Debentures | Debenture 2020A, 3.35 Percent, Due 2030
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.35%
TOTAL		$ 600	0
Debentures | Debenture 2020A, 3.35 Percent, Due 2030 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.35%
TOTAL		$ 600	0
Debentures | Debenture 2020A, 2.02 Percent, Due 2030
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.02%
TOTAL		$ 35	0
Debentures | Debenture Series 2003A, 5.875% Due 2033
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.875%
TOTAL		$ 175	175
Debentures | Debenture Series 2003A, 5.875% Due 2033 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.875%
TOTAL		$ 175	175
Debentures | Debenture Series 2003C, 5.10% Due 2033
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.10%
TOTAL		$ 200	200
Debentures | Debenture Series 2003C, 5.10% Due 2033 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.10%
TOTAL		$ 200	200
Debentures | Debenture Series 2004B, 5.70% Due 2034
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 200	200
Debentures | Debenture Series 2004B, 5.70% Due 2034 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 200	200
Debentures | Debenture Series 2005A, 5.30% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.30%
TOTAL		$ 350	350
Debentures | Debenture Series 2005A, 5.30% Due 2035 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.30%
TOTAL		$ 350	350
Debentures | Debenture Series 2005B, 5.25% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
TOTAL		$ 125	125
Debentures | Debenture Series 2005B, 5.25% Due 2035 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
TOTAL		$ 125	125
Debentures | Debenture Series 2006A, 5.85% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.85%
TOTAL		$ 400	400
Debentures | Debenture Series 2006A, 5.85% Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.85%
TOTAL		$ 400	400
Debentures | Debenture Series 2006B, 6.20% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.20%
TOTAL		$ 400	400
Debentures | Debenture Series 2006B, 6.20% Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.20%
TOTAL		$ 400	400
Debentures | Debenture Series 2006E, 5.70% Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 250	250
Debentures | Debenture Series 2006E, 5.70% Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 250	250
Debentures | Debenture Series 2007A, 6.30% Due 2037
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.30%
TOTAL		$ 525	525
Debentures | Debenture Series 2007A, 6.30% Due 2037 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.30%
TOTAL		$ 525	525
Debentures | Debenture 2008B, 6.75 Percent, Due 2038
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.75%
TOTAL		$ 600	600
Debentures | Debenture 2008B, 6.75 Percent, Due 2038 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.75%
TOTAL		$ 600	600
Debentures | Debenture 2009B, 6.00 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.00%
TOTAL		$ 60	60
Debentures | Debenture 2009C, 5.50 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 600	600
Debentures | Debenture 2009C, 5.50 Percent, Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 600	600
Debentures | Debenture 2019C, 3.46 Percent, Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.46%
TOTAL		$ 38	38
Debentures | Debenture 2010B, 5.70 Percent, Due 2040
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 350	350
Debentures | Debenture 2010B, 5.70 Percent, Due 2040 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 350	350
Debentures | Debenture 2010B, 5.50 Percent, Due 2040
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 115	115
Debentures | Debenture 2012A, 4.20 Percent, Due 2042
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.20%
TOTAL		$ 400	400
Debentures | Debenture 2012A, 4.20 Percent, Due 2042 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.20%
TOTAL		$ 400	400
Debentures | Debenture 2013A, 3.95 Percent, Due 2043
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 700	700
Debentures | Debenture 2013A, 3.95 Percent, Due 2043 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 700	700
Debentures | Debenture 2014A, 4.45 Percent, Due 2044
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 850	850
Debentures | Debenture 2014A, 4.45 Percent, Due 2044 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 850	850
Debentures | Debenture 2015A, 4.50 Percent, Due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 650	650
Debentures | Debenture 2015A, 4.50 Percent, Due 2045 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 650	650
Debentures | Debenture 2015A, 4.95 Percent, Due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.95%
TOTAL		$ 120	120
Debentures | Debenture Series 2015B, 4.69% due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.69%
TOTAL		$ 100	100
Debentures | Debenture 2016A, 3.85 Percent, Due 2046
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.85%
TOTAL		$ 550	550
Debentures | Debenture 2016A, 3.85 Percent, Due 2046 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.85%
TOTAL		$ 550	550
Debentures | Debenture Series 2016A. 3.88% Due 2046
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.88%
TOTAL		$ 75	75
Debentures | Debenture Series 2017A, 3.875% Due 2047
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.875%
TOTAL		$ 500	500
Debentures | Debenture Series 2017A, 3.875% Due 2047 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.875%
TOTAL		$ 500	500
Debentures | Debenture Series 2018E, 4.65% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.65%
TOTAL		$ 600	600
Debentures | Debenture Series 2018E, 4.65% Due 2048 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.65%
TOTAL		$ 600	600
Debentures | Debenture Series 2018A, 4.35% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.35%
TOTAL		$ 125	125
Debentures | Debenture Series 2018B, 4.35% Due 2048
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.35%
TOTAL		$ 25	25
Debentures | Debenture 2019A, 4.125 Percent, Due 2049
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.125%
TOTAL		$ 700	700
Debentures | Debenture 2019A, 4.125 Percent, Due 2049 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.125%
TOTAL		$ 700	700
Debentures | Debenture 2019A, 3.73 Percent, Due 2049
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.73%
TOTAL		$ 43	43
Debentures | Debenture 2020B, 3.95 Percent, Due 2050
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 1,000	0
Debentures | Debenture 2020B, 3.95 Percent, Due 2050 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 1,000	0
Debentures | Debenture 2020B, 3.24 Percent, Due 2050
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.24%
TOTAL		$ 40	0
Debentures | Debenture Series 2014C, 4.625% Due 2054
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.625%
TOTAL		$ 750	750
Debentures | Debenture Series 2014C, 4.625% Due 2054 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.625%
TOTAL		$ 750	750
Debentures | Debenture Series 2016C, 4.30% Due 2056
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.30%
TOTAL		$ 500	500
Debentures | Debenture Series 2016C, 4.30% Due 2056 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.30%
TOTAL		$ 500	500
Debentures | Debenture Series 2017C, 4.00% Due 2057
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
TOTAL		$ 350	350
Debentures | Debenture Series 2017C, 4.00% Due 2057 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.00%
TOTAL		$ 350	350
Debentures | Debenture Series 2018B, 4.50% Due 2058
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 700	700
Debentures | Debenture Series 2018B, 4.50% Due 2058 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 700	700
Debentures | Debenture 2019B, 3.70 Percent, Due 2059
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.70%
TOTAL		$ 600	600
Debentures | Debenture 2019B, 3.70 Percent, Due 2059 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.70%
TOTAL		$ 600	600
Debentures | Debenture 2020C, 3.00 Percent, Due 2060
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.00%
TOTAL		$ 600	0
Debentures | Debenture 2020C, 3.00 Percent, Due 2060 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.00%
TOTAL		$ 600	0
Debentures | Debenture 2018C, 2.75 Percent, Due 2021 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.65%
TOTAL		$ 640	640
Tax-Exempt Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL PROJECT DEBT		450	450
Tax-Exempt Debt | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 450	450
Tax-Exempt Debt | Tax Exempt Debt Series 2010A Due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.11%
TOTAL PROJECT DEBT	[2]	$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2010A Due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.11%
TOTAL	[3]	$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 1.663% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.11%
TOTAL PROJECT DEBT	[2]	$ 99	99
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 1.663% Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.11%
TOTAL	[3]	$ 99	99
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 1.627% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.09%
TOTAL PROJECT DEBT	[2]	$ 126	126
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 1.627% Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.09%
TOTAL	[3]	$ 126	$ 126

[1] December 31, 2020 effective rates shown, reflecting variable interest rates on the debt that are reset quarterly or semi-annually and the effect of applicable interest rate swaps, if any

[2] Rates reset weekly or quarterly; December 31, 2020 rates shown.

[3] Rates reset weekly or quarterly; December 31, 2020 rates shown.

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General

12 Months Ended

Dec. 31, 2020

Organization, Consolidation and Presentation of Financial Statements [Abstract]

General

General

These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the two separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Orange and Rockland Utilities, Inc. (O&R), Con Edison Clean Energy Businesses, Inc. (together with its subsidiaries, the Clean Energy Businesses) and Con Edison Transmission, Inc. (together with its subsidiaries, Con Edison Transmission) in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R.

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

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., which through its subsidiaries develops, owns and operates renewable and sustainable energy infrastructure projects and provide energy-related products and services to wholesale and retail customers. In December 2018, the Clean Energy Businesses acquired Sempra Solar Holdings, LLC. Con Edison Transmission, Inc. invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and holds investments in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See Note V.

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Summary of Significant Accounting Policies and Other Matters

12 Months Ended

Dec. 31, 2020

Accounting Policies [Abstract]

Summary of Significant Accounting Policies and Other Matters

Summary of Significant Accounting Policies and Other Matters

Principles of Consolidation

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

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.

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

The Utilities’ principal regulatory assets and liabilities are detailed in Note B. In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities at December 31, 2020 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by state regulators.

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

Financial Instruments – Credit Losses

Adoption of New Standard

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.” The amendments replace the incurred loss impairment methodology which involved delayed recognition of credit losses. The amendments introduce an expected credit loss impairment model which requires immediate recognition of anticipated losses over the instrument’s life. A broader range of reasonable and supportable information must be considered in developing the credit loss estimates. The Companies' financial instruments subject to the amendments are included in the lines “Accounts receivable – customers” and “Other receivables.” Substantially all of these in-scope financial instruments are expected to be collected within one year of billing.

The Companies adopted the amendments using the modified retrospective method for all financial instruments measured at amortized costs. Results for reporting periods beginning after January 1, 2020 are presented under Accounting Standards Codification (ASC) 326 while prior period amounts continue to be reported in accordance with previously applicable GAAP. No prior period adjustment or charge to retained earnings for cumulative impact was required as a result of the Companies’ adoption of the amendments.

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 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, 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.

During the year of 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 customer uncollectible accounts for Con Edison and CECONY were $78 million and $73 million, respectively, for the year ended December 31, 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 year ended December 31, 2020:

	For the Year Ended December 31, 2020
	Con Edison		CECONY
(Millions of Dollars)	Accounts receivable - customers	Other receivables	Accounts receivable - customers	Other receivables
Allowance for credit losses
Beginning Balance at January 1, 2020	$70	$4	$65	$3
Recoveries	8	—	6	—
Write-offs	(54)	(2)	(50)	(1)
Reserve adjustments	124	5	117	2
Ending Balance December 31, 2020	$148	$7	$138	$4

Revenues

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

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

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$335	$323	$330
CECONY	323	312	318

For information about the Companies' revenue recognition policies, see Note M.

Plant and Depreciation

Utility Plant

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

Rates used for AFUDC include the cost of borrowed funds and a reasonable rate of return on the Utilities’ own funds when so used, determined in accordance with regulations of the FERC or the state public utility regulatory authority having jurisdiction. The rate is compounded semiannually, and the amounts applicable to borrowed funds are treated as a reduction of interest charges, while the amounts applicable to the Utilities’ own funds are credited to other income (deductions). The AFUDC rates for CECONY were 5.2 percent, 5.1 percent and 5.4 percent for 2020, 2019 and 2018, respectively. The AFUDC rates for O&R were 5.3 percent, 5.3 percent and 2.2 percent for 2020, 2019 and 2018, respectively.

The Utilities generally compute annual charges for depreciation using the straight-line method for financial statement purposes, with rates based on average service lives and net salvage factors. The average depreciation rates for CECONY were 3.5 percent for 2020 and 3.2 percent for 2019 and 2018. The average depreciation rates for O&R were 3.2 percent for 2020, 3.0 percent for 2019 and 2.9 percent for 2018.

The estimated lives for utility plant for CECONY range from 5 to 85 years for electric, 5 to 90 years for gas, 5 to 80 years for steam and 5 to 55 years for general plant. For O&R, the estimated lives for utility plant range from 5 to 75 years for electric and gas and 5 to 50 years for general plant.

At December 31, 2020 and 2019, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Electric
Generation	$572	$591	$572	$591
Transmission	3,786	3,634	3,496	3,380
Distribution	21,481	20,676	20,366	19,602
General	52	43	52	43
Gas (a)	9,206	8,617	8,522	7,961
Steam	1,854	1,813	1,854	1,813
General	2,507	2,365	2,286	2,143
Held for future use	92	75	84	67
Construction work in progress	2,474	1,937	2,320	1,812
Net Utility Plant	$42,024	$39,751	$39,552	$37,412

(a) Primarily distribution.

General utility plant of Con Edison and CECONY included $86 million and $81 million, respectively, at December 31, 2020, and $93 million and $88 million, respectively, at December 31, 2019, related to a May 2018 acquisition of software licenses. The estimated aggregate annual amortization expense for Con Edison and CECONY is $7 million. The accumulated amortization for Con Edison and CECONY was $17 million at December 31, 2020 and $10 million at December 31, 2019.

Under the Utilities’ rate plans, the aggregate annual depreciation allowance for the period ended December 31, 2020 was $1,694 million, including $1,604 million under CECONY’s electric, gas and steam rate plans that have been approved by the NYSPSC.

Non–Utility Plant

Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the Clean Energy Businesses’ renewable electric production projects. Property, plant and equipment are stated at cost, less accumulated depreciation and include capitalized interest during construction. Depreciation is computed under the straight-line method over the useful lives of the assets. Solar power generating assets and wind power generating assets have useful lives of 35 years and 30, respectively. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives, which is 10 years.

Other Deferred Charges and Noncurrent Assets and Prepayments

Other deferred charges and noncurrent assets and prepayments of Con Edison, net of accumulated depreciation, included $54 million ($51 million for CECONY) and $12 million ($11 million for CECONY), respectively at December 31, 2020, related to implementation costs incurred in cloud computing arrangements. The amounts recorded in 2019 were not material. Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. Depreciation expense related to these assets incurred during the year ended December 31, 2020 for Con Edison and CECONY was $7 million and $6 million, respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $10 million and $8 million, respectively at December 31, 2020 and was not material at December 31, 2019.

Long–Lived and Intangible Assets

The Companies 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 carrying amount of a long-lived asset or intangible asset with a definite life is deemed not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the assets. In the event a test indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are considered impaired and written down to their estimated fair value.

Con Edison's intangible assets with definite lives consist primarily of power purchase agreements, which were identified as part of purchase price allocations associated with acquisitions made by the Clean Energy Businesses in 2016 and 2018. At December 31, 2020 and 2019, intangible assets arising from power purchase agreements, including the PG&E PPAs (discussed below), were $1,457 million and $1,554 million, net of accumulated amortization of $220 million and $119 million, respectively, and are being amortized over the life of each agreement. Excluding power purchase agreements, Con Edison’s other intangible assets were $3 million, net of accumulated amortization of $8 million and $7 million, at December 31, 2020 and 2019, respectively. CECONY’s other intangible assets were immaterial at December 31, 2020 and 2019. Con Edison recorded amortization expense related to its intangible assets of $102 million in 2020, $99 million in 2019, and $14 million in 2018. Con Edison expects amortization expense to be $102 million per year over the next five years. Con Edison recorded $2 million of impairment charges in 2018. No impairment charges were recorded on Con Edison's long-lived assets or intangible assets with definite lives in 2020 or 2019.

In January 2019, Pacific Gas and Electric Company (PG&E) filed for reorganization under Chapter 11 of the U.S. Bankruptcy Code. The output of certain of the Clean Energy Businesses' renewable electric production projects is sold to PG&E under long-term power purchase agreements. As a result of the PG&E bankruptcy, distributions from the related projects to the Clean Energy Businesses were restricted and PG&E-related project debt was reclassified on Con Edison’s consolidated balance sheet from long-term debt to long-term debt due within one year. In July 2020, PG&E’s plan of reorganization became effective and the Clean Energy Businesses began receiving previously restricted distributions and all related project debt with a maturity longer than one year was reclassified to long-term debt.

Recoverable Energy Costs

The Utilities generally recover all of their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state public utility regulators. If the actual energy supply costs for a given month are more or less than the amounts billed to customers for that month,

the difference in most cases is recoverable from or refundable to customers. Differences between actual and billed electric and steam supply costs and costs of its electric demand management programs are generally deferred for charge or refund to customers during the next billing cycle (normally within one or two months). For the Utilities’ gas costs, differences between actual and billed gas costs during the 12-month period ending each August are charged or refunded to customers during a subsequent 12-month period.

New York Independent System Operator (NYISO)

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

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

Temporary Cash Investments

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

Investments

Accounting for 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.

The accounting rules require Con Edison to periodically evaluate its investments 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 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 involves 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 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.

Con Edison evaluated its equity method investments and determined that there was an other-than-temporary decline in the value of its investment in Mountain Valley Pipeline LLC (MVP) and therefore recorded a partial impairment at December 31, 2020, as described below. Also, Con Edison is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC (Stagecoach), a joint venture that owns and operates an existing gas pipeline and storage business located in northeastern Pennsylvania and the southern tier of New York. As such strategic alternatives are evaluated, Con Edison may be required to determine whether an other-than-temporary decline in value has occurred for its Stagecoach investment.

Partial Impairment of Investment in Mountain Valley Pipeline LLC (MVP)

In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET Gas), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed gas transmission project (the Project) in West Virginia and Virginia. At December 31, 2020 and 2019, CET Gas' cash contributions to MVP were approximately $530 million, and the carrying value at December 31, 2020 prior to recording an impairment loss was

$662 million, reflecting CET Gas' proportionate share of allowance for funds used during construction (AFUDC) income from the Project. During 2019, Con Edison determined that, as it was permitted to do under the MVP joint venture agreement, it would limit its cash contributions to the joint venture to approximately $530 million, which limit was reached in 2019, and that is expected to result in the further reduction of Con Edison’s ownership share in the joint venture. At December 31, 2020, CET Gas owned an 11.3 percent interest in MVP that is expected to be reduced to 8.8 percent based on the current project cost estimate and CET Gas’ previous capping of its cash contributions to the joint venture.

During 2020, progress was made on the construction of the Project, and the U.S. Supreme Court issued favorable decisions in cases unrelated to MVP, regarding the permitting process for pipeline construction and water crossings. In November 2020, the U.S. Court of Appeals for the Fourth Circuit issued a stay on the Nationwide Permit 12, effectively blocking the Project’s ability to pursue water crossings under that permit. As a result, in November 2020 the Project applied to the FERC for a certificate amendment to bore under water bodies in the first 77 miles of the Project in West Virginia, allowing this portion of the pipe to be completed and placed in-service while a plan for the remaining water crossings was pursued. If approved, this amendment would lead to additional Project costs and would extend the anticipated in-service date of the Project to late 2021. The uncertainty related to obtaining the necessary permits in lieu of the Nationwide Permit 12, the resulting Project costs and the likelihood of the Project not reaching eventual completion have increased, constituting a triggering event which required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. Further, in January 2021, the FERC did not approve the requested amendment. In its discussion, a FERC commissioner indicated that the commission should have the plan for the entire Project’s water crossings rather than the first 77 miles and that all of the Federal permits be restored before allowing additional construction to resume. Later in January 2021, the Project indicated its plans to apply for U.S. Army Corps of Engineers individual permits for certain water crossings and a certificate amendment for other water crossings that, in total, would cover the entire Project length. In addition, the second largest partner in the Project announced it had recorded a significant impairment of their investment in the Project at year-end 2020.

In response to the triggering event, Con Edison assessed the value of its equity investment in the Project to determine whether the fair value of its investment in MVP had declined below its carrying value on an other-than-temporary basis. The estimated fair value of the investment was determined using a discounted cash flow analysis, which is a level 3 fair value measurement. The analysis discounted probability-weighted future cash flows, including revenues based on long-term firm transportation contracts, that are secured for the first 20 years following completion of the Project. See Note T. Con Edison has also assumed cash flows extending beyond this period. All cash flows were discounted at a pre-tax discount rate of 8.3 percent and then weighted based on Con Edison’s estimate of the likelihood that the Project will be completed. Con Edison believes that the likelihood of Project completion is in the upper end of a reasonably possible range. The likelihood that the Project is completed and the discount rate are the most significant and sensitive assumptions; changes in these assumptions may materially change the results of the impairment calculation.

Based on the discounted cash flow analysis, Con Edison concluded that the fair value of its investment in MVP declined below its carrying value and the decline is other-than-temporary. Accordingly, Con Edison recorded a pre-tax impairment loss of $320 million ($223 million, after tax), for the year ended December 31, 2020 to reduce the carrying value of its investment in MVP from $662 million to $342 million. The impairment was recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison will not record non-cash equity in earnings from allowance for funds used during construction, if any, from MVP beginning in 2021 and until such time as substantial construction activities are resumed, which would be indicative of probable Project completion.

There is risk that the fair value of Con Edison’s investment in MVP may be further or fully impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before the Project can be completed. Assumptions and estimates used to test Con Edison’s investment in MVP for impairment may change if adverse or delayed resolutions to the Project’s pending legal and regulatory challenges were to occur, which could have a material adverse effect on the fair value of Con Edison’s investment in MVP.

Summary of Investment Balances

The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2020 and 2019:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
CET Gas investment in Stagecoach Gas Services, LLC	$845	$924	$—	$—
CET Gas investment in Mountain Valley Pipeline, LLC (a)	342	602	—	—
Supplemental retirement income plan assets (b)	465	397	439	371
Deferred income plan assets	92	81	92	81
CET Electric investment in New York Transco, LLC	69	59	—	—
Other	3	2	10	9
Total investments	$1,816	$2,065	$541	$461

(a)At December 31, 2020 and 2019, CET Gas' cash investment in MVP was $530 million. In January 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is continuing to target an in-service date for the Project of late 2021 at an overall Project cost of $5,800 million to $6,000 million, excluding allowance for funds used during construction. For the year ended December 31, 2020, CET Gas owned an 11.3 percent interest in MVP and reduced the carrying value of its investment in MVP from $662 million to $342 million by recognizing a noncash impairment loss of $320 million, pre-tax ($223 million, after tax), and based on total estimated Project costs and CET Gas’ previous capping of its cash contributions to the joint venture, its ownership interest in the joint venture is expected to be reduced to 8.8%.

(b)See Note E.

Pension and Other Postretirement Benefits

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

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

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

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

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

Federal Income Tax

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

Upon enactment of the Tax Cuts and Jobs Act of 2017 on December 22, 2017 (the TCJA), the Companies re-measured their deferred tax assets and liabilities based upon the 21 percent corporate income tax rate under the TCJA. The tax effects of changes in tax laws are to be recognized in the period in which the law is enacted and deferred tax assets and liabilities are to be re-measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. For the Utilities, in accordance with their New York rate plans and the accounting rules for regulated operations, the change in deferred taxes was recorded as either an offset to a regulatory asset or a regulatory liability. For Con Edison’s other businesses, the change in deferred taxes was reflected as a decrease in income tax expense, which increased Con Edison's net income. See “Other Regulatory Matters” and “Regulatory Assets and Liabilities” in Note B and Note L.

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

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

State Income Tax

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

Research and Development Costs

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

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$24	$24	$24
CECONY	23	23	23

Reclassification

Certain prior year amounts have been reclassified within Note L to conform with current year 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 are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.

Potentially dilutive securities for Con Edison consist of restricted stock units and deferred stock units for which the average market price of the common shares for the period was greater than the exercise price (see Note N) and its common shares that are subject to forward sale agreements (see Note C). Before the issuance of common shares upon settlement of the forward sale agreements, the shares will be reflected in the company’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of common shares used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreements over the number of shares that could be purchased by the company in the market (based on the average market price during the period) using the proceeds due upon physical settlement (based on the adjusted forward sale price at the end of the reporting period).

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

	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2020	2019	2018
Net income for common stock	$1,101	$1,343	$1,382
Weighted average common shares outstanding – basic	334.8	328.5	311.7
Add: Incremental shares attributable to effect of potentially dilutive securities	0.9	1.0	1.2
Adjusted weighted average common shares outstanding – diluted	335.7	329.5	312.9
Net Income per common share – basic	$3.29	$4.09	$4.43
Net Income per common share – diluted	$3.28	$4.08	$4.42

The computation of diluted EPS for the years ended December 31, 2020, 2019 and 2018 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect.

Estimates

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

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

Changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:

(Millions of Dollars)	Con Edison	CECONY
Accumulated OCI, net of taxes, at December 31, 2017 (a)	$(26)	$(6)
OCI before reclassifications, net of tax of $3 for Con Edison	4	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	6	1
Total OCI, net of taxes, at December 31, 2018	10	1
Accumulated OCI, net of taxes, at December 31, 2018 (a)	$(16)	$(5)
OCI before reclassifications, net of tax of $(6) and $(1) for Con Edison and CECONY, respectively	(10)	(3)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	7	2
Total OCI, net of taxes, at December 31, 2019	(3)	(1)
Accumulated OCI, net of taxes, at December 31, 2019 (a)	$(19)	$(6)
OCI before reclassifications, net of tax of $4 and $1 for Con Edison and CECONY, respectively	(11)	(3)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	5	2
Total OCI, net of taxes, at December 31, 2020	(6)	(1)
Accumulated OCI, net of taxes, at December 31, 2020 (a)	$(25)	$(7)

(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 cost. See Notes E and F.

Reconciliation of Cash, Temporary Cash Investments and Restricted Cash

Cash, temporary cash investments and restricted cash are presented on a combined basis in the Companies’ consolidated statements of cash flows. At December 31, 2020 and 2019, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows:

	At December 31,
	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Cash and temporary cash investments	$1,272	$981	$1,067	$933
Restricted cash (a)	164	236	—	—
Total cash, temporary cash investments and restricted cash	$1,436	$1,217	$1,067	$933

(a)Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($164 million and $236 million at December 31, 2020 and 2019, respectively) that, under the related project debt agreements, is either restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves or, for the December 31, 2019 amount, was restricted as a result of the PG&E bankruptcy. During the pendency of the PG&E bankruptcy, cash was not distributed from the related projects to the Clean Energy Businesses. In July 2020, PG&E's plan of reorganization became effective and the Clean Energy Businesses received previously restricted distributions and have resumed receiving distributions for all projects. See "Long-Lived and Intangible Assets,” above.

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Regulatory Matters

12 Months Ended

Dec. 31, 2020

Regulated Operations [Abstract]

Regulatory Matters

Regulatory Matters

Rate Plans

The Utilities provide service to New York customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary, are approved by the NJBPU. The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator.

Common provisions of the Utilities’ New York rate plans include:

Recoverable energy costs that allow the Utilities to recover on a current basis the costs for the energy they supply with no mark-up to their full-service customers.

Cost reconciliations that reconcile pension and other postretirement benefit costs, environmental remediation costs, property taxes, variable-rate tax-exempt debt and certain other costs to amounts reflected in delivery rates for such costs. In addition, changes in the Utilities' costs not reflected in rates, in excess of certain amounts, resulting from changes in tax or changes in legislation, regulation or related actions, are deferred as a regulatory asset or regulatory liability to be reflected in the Utilities' next rate plan or in a manner to be determined by the NYSPSC. Also, the Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases and provision is sometimes made for the utility to retain a share of cost reductions, for example, property tax refunds.

Revenue decoupling mechanisms that reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC. The difference is accrued with interest for refund to, or recovery from customers, as applicable.

Earnings sharing that require the Utilities to defer for customer benefit a portion of earnings over specified rates of return on common equity. There is no symmetric mechanism for earnings below specified rates of return on common equity.

Negative revenue adjustments for failure to meet certain performance standards relating to service, reliability, safety and other matters.

Positive revenue adjustments for achievement of performance standards related to achievement of clean energy goals, safety and other matters.

Net utility plant reconciliations that require deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates. There is generally no symmetric mechanism if actual average net utility plant balances are more than amounts reflected in rates.

Rate base, as reflected in the rate plans, is, in general, the sum of the Utilities’ net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. For each rate plan, the NYSPSC uses a forecast of the average rate base for each year that new rates would be in effect (“rate year”). 

Weighted average cost of capital is determined based on the authorized common equity ratio, return on common equity, cost of long-term debt and cost of customer deposits reflected in each rate plan. For each rate plan, the revenues designed to provide the utility a return on invested capital for each rate year are determined by multiplying each utility rate base by its pre–tax weighted average cost of capital. The Utilities’ actual return on common equity will reflect their actual operations for each rate year, and may be more or less than the authorized return on equity reflected in their rate plans (and if more, may be subject to earnings sharing).

The following tables contain a summary of the Utilities’ rate plans:

CECONY – Electric
Effective period	January 2017 – December 2019	January 2020 – December 2022 (a)
Base rate changes	Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b)	Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million	Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d)
Other revenue sources	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively.	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020, the company recorded $34 million primarily related to earnings adjustment mechanism incentives for energy efficiency.
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, the company deferred for recovery from customers $242 million of revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel 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 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million.	Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively.	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2020, the company deferred $288 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively.	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020.
Average rate base	Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million	Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent	6.61 percent
Authorized return on common equity	9.0 percent	8.80 percent

Actual return on common equity (i)	Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent	Yr. 1 – 8.50 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold.	Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, the company had no earnings sharing above the threshold.
Cost of long-term debt	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent	4.63 percent
Common equity ratio	48 percent	48 percent

(a)In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note T) are not necessary.

(b)The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs.

(c)Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d)Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually).

(e)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.

(f)In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of

30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan.

(g)In addition, the NYSPSC staff has commenced a focused operations audit to investigate the income tax accounting of CECONY and other New York utilities. Any NYSPSC-ordered adjustment to CECONY’s income tax accounting will be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below.

(h)Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas.

(i)Calculated in accordance with the earnings calculation method prescribed in the rate order.

CECONY – Gas
Effective period	January 2017 - December 2019	January 2020 – December 2022 (a)
Base rate changes	Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million	Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million	Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d)
Other revenue sources	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations.	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020, the company recorded $3 million of earnings adjustment mechanism incentives for energy efficiency. In 2020, the company recorded positive incentives of $13 million.
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, the company deferred for recovery from customers $27 million of revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas 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 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any negative revenue adjustments.	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $81 million Yr. 2 - $88 million Yr. 3 - $96 million In 2020, the company did not record any negative revenue adjustments.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively.	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2020, the company deferred $91 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability.	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $8,108 million Yr. 2 - $8,808 million Yr. 3 - $9,510 million AMI: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020, the company deferred $24.7 million as a regulatory liability.
Average rate base	Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million	Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent	6.61 percent
Authorized return on common equity	9.0 percent	8.80 percent
Actual return on common equity (i)	Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent	Yr. 1 – 8.40 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold.	Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent	4.63 percent
Common equity ratio	48 percent	48 percent

(a)In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note T) are not necessary.

(b)The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(c)The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d)Amounts reflect amortization of the remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually)

(e)-(i)    See footnotes (e) - (i) to the table under “CECONY Electric,” above.

CECONY – Steam
Effective period	January 2014 – December 2016 (a)
Base rate changes	Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None
Amortizations to income of net regulatory (assets) and liabilities	$37 million over three years
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2020, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015, 2016, 2017, 2018, 2019 and 2020, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities and $35 million of net regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020.
Average rate base	Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent
Authorized return on common equity	9.3 percent
Actual return on common equity (d)	Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent
Earnings sharing	Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent
Common equity ratio	48 percent

(a)Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC.

(b)The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016.

(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 10 basis point impact on return on common equity.

(d)Calculated in accordance with the earnings calculation method prescribed in the rate order.

O&R New York – Electric
Effective period	November 2015 - October 2017 (a)	January 2019 – December 2021 (d)
Base rate changes	Yr. 1 – $9.3 million Yr. 2 – $8.8 million Yr. 3 – None	Yr. 1 – $13.4 million (e) Yr. 2 – $8.0 million (e) Yr. 3 – $5.8 million (e)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $(8.5) million (b) Yr. 2 – $(9.4) million (b) Yr. 3 – None	Yr. 1 – $(1.5) million (f) Yr. 2 – $(1.5) million (f) Yr. 3 – $(1.5) million (f)
Other revenue sources		Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019 and 2020, the company recorded $2.6 million and $1.9 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively.
Revenue decoupling mechanisms	In 2015, 2016, 2017 and 2018, the company deferred for the customer’s benefit an immaterial amount, $6.3 million as regulatory liabilities, $11.2 million as regulatory asset and $0.5 million as regulatory asset, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million as regulatory assets.
Recoverable energy costs	Continuation of current rate recovery of purchased power costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential charges (up to $4 million annually) if certain performance targets are not met. In 2015 the company recorded $1.25 million in negative revenue adjustments. In 2016, 2017 and 2018, the company did not record any negative revenue adjustments.	Potential charges if certain performance targets relating to service, reliability and other matters are not met: Yr. 1 - $4.4 million Yr. 2 - $4.4 million Yr. 3 - $4.5 million In 2019 and 2020, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2015, 2016 and 2017, the company deferred $0.3 million, $7.4 million and $3.2 million as net decreases to regulatory assets, respectively. In 2018, the company deferred $5 million as a net regulatory asset.	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), major storms, the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $4.3 million and $30.3 million as net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates are: Yr. 1 – $928 million (c) Yr. 2 – $970 million (c) The company increased/(reduced) its regulatory asset by $2.2 million, $(1.9) million, $(1.9) million and $1.4 million in 2015, 2016, 2017 and 2018, respectively.	Target levels reflected in rates were: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $1,008 million Yr. 2 - $1,032 million Yr. 3 - $1,083 million AMI (j): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019 and deferred $0.4 million as a regulatory liability in 2020.
Average rate base	Yr. 1 – $763 million Yr. 2 – $805 million Yr. 3 – $805 million	Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent	Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent
Authorized return on common equity	9.0 percent	9.0 percent
Actual return on common equity (k)	Yr. 1 – 10.8 percent Yr. 2 – 9.7 percent Yr. 3 – 7.2 percent	Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $6.1 million, $0.3 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold.
Cost of long-term debt	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent	Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent
Common equity ratio	48 percent	48 percent

(a)Rates determined pursuant to this rate plan continued in effect until the subsequent rate plan became effective.

(b)$59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a 5 year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015.

(c)Excludes electric AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2.

(d)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 (see Note T) are not necessary.

(e)The electric base rate increases shown above will be implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million.

(f)Reflects amortization of, among other things, the company’s net benefits under the TCJA prior to January 1, 2019, amortization of net regulatory liability for future income taxes and reduction of previously incurred regulatory assets for environmental remediation costs. Also, for electric, reflects amortization over a six year period of previously incurred incremental major storm costs. See "Other Regulatory Matters," below.

(g)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.

(h)Energy efficiency costs are expensed as incurred. Such costs are subject to a downward-only reconciliation over the terms of the electric and gas rate plans. The company will defer for the benefit of customers any cumulative shortfall over the terms of the electric and gas rate plans between actual expenditures and the levels provided in rates.

(i)In addition, amounts reflected in rates relating to income taxes and excess deferred federal income tax liability balances will be reconciled (i.e., refunded to or collected from customers) to any final, non-appealable NYSPSC-ordered findings in its investigation of O&R’s income tax accounting. See “Other Regulatory Matters,” in Note B.

(j)Net plant reconciliation for AMI expenditures will be implemented for a single category of AMI capital expenditures that includes amounts allocated to both electric and gas customers.

(k)Calculated in accordance with the earnings calculation method prescribed in the rate order.

In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective January 1, 2022, of $24.5 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased power, and the reconciliation of actual expenses allocable to the electric business to the amounts for such costs reflected in electric rates for storm costs, pension and other postretirement benefit costs, environmental remediation and property taxes.

O&R New York – Gas
Effective period	November 2015 – October 2018 (a)	January 2019 – December 2021 (d)
Base rate changes	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge	Yr. 1 – $(7.5) million (e) Yr. 2 – $3.6 million (e) Yr. 3 – $0.7 million (e)
Amortization to income of net regulatory (assets) and liabilities	Yr. 1 – $(1.7) million (b) Yr. 2 – $(2.1) million (b) Yr. 3 – $(2.5) million (b)	Yr. 1 – $1.8 million (f) Yr. 2 – $1.8 million (f) Yr. 3 – $1.8 million (f)
Other revenue sources		Continuation of retention of annual revenues from non-firm customers of up to $4.0 million, with variances to be shared 80 percent by customers and 20 percent by company. Potential earnings adjustment mechanism incentives of up to $0.3 million annually. Potential incentives if performance targets related to gas leak backlog, leak prone pipe, emergency response, damage prevention and customer service are met: Yr. 1 - $1.2 million; Yr. 2 - $1.3 million; and Yr. 3 - $1.3 million. In 2019 and 2020, the company recorded $0.3 million of earnings adjustment mechanism incentives for energy efficiency. In 2019 and 2020, the company recorded $0.7 million and $0.5 million of positive incentives, respectively.
Revenue decoupling mechanisms	In 2015, 2016, 2017 and 2018, the company deferred $0.8 million of regulatory assets, $6.2 million of regulatory liabilities, $1.7 million of regulatory liabilities and $6.3 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2019 and 2020, the company deferred $0.8 million and $0.5 million of regulatory assets, respectively.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential charges (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $4.9 million in Yr. 3) if certain performance targets are not met. In 2015, 2016 and 2017, the company did not record any negative revenue adjustments. In 2018, the company recorded a $0.1 million negative revenue adjustment.	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $5.5 million; Yr. 2 - $5.7 million; and Yr. 3 - $6.0 million. In 2019 and 2020, the company recorded a $0.2 million and an immaterial amount of negative revenue adjustments, respectively.
Cost reconciliations	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively. In 2017 and 2018, the company deferred $3.5 million and $7.4 million as net regulatory liabilities, respectively.	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $6 million as net regulatory liabilities and $1.8 million as net regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates are: Yr. 1 – $492 million (c) Yr. 2 – $518 million (c) Yr. 3 – $546 million (c) No deferral was recorded for 2015 and immaterial amounts were recorded as regulatory liabilities in 2016 and 2017. In 2018, the company deferred $0.4 million as regulatory asset.	Target levels reflected in rates were: Gas average net plant target excluding AMI: Yr. 1 - $593 million Yr. 2 - $611 million Yr. 3 - $632 million AMI (j): Yr. 1 - $20 million Yr. 2 - $24 million Yr. 3 - $25 million In 2019 and 2020, the company deferred immaterial amounts as regulatory assets.
Average rate base	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million	Yr. 1 – $454 million Yr. 2 – $476 million Yr. 3 – $498 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent	Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent
Authorized return on common equity	9.0 percent	9.0 percent
Actual return on common equity (k)	Yr. 1 – 11.2 percent Yr. 2 – 9.7 percent Yr. 3 – 8.1 percent	Yr. 1 – 8.90 percent Yr. 2 – 9.58 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million, $0.2 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold.
Cost of long-term debt	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent	Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent
Common equity ratio	48 percent	48 percent

(a)Rates pursuant to this rate plan continued in effect until the subsequent rate plan became effective.

(b)Reflects that the company will not recover from customers a total of approximately $14 million of regulatory assets for property tax and interest rate reconciliations. Amounts that will not be recovered from customers were charged-off in June 2015.

(c)Excludes gas AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $0.5 million in year 1, $4.2 million in year 2 and $7.2 million in year 3.

(d)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 (see Note T) are not necessary.

(e)The gas base rate changes shown above will be implemented with changes of: Yr. 1 - $(5.9) million; Yr. 2 - $1.0 million; and Yr. 3 - $1.0 million.

(f)-(k) See footnotes (f) - (k) to the table under “O&R New York - Electric,” above.

In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for gas service rendered in New York, effective January 1, 2022, of $9.8 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased gas, and the reconciliation of actual expenses allocable to the gas business to the amounts for such costs reflected in gas rates for pension and other postretirement benefit costs, environmental remediation and property taxes.

In January 2020, the NJBPU approved an electric rate increase, effective February 1, 2020, of $12 million for RECO. The following table contains a summary of the terms of the distribution rate plans.

RECO
Effective period	March 2017 – January 2020	February 2020
Base rate changes	Yr. 1 – $1.7 million	Yr. 1 – $12 million
Amortization to income of net regulatory (assets) and liabilities	$0.2 million over three years and continuation of $(25.6) million of deferred storm costs over four years which expired on July 31, 2018 (a)	$4.8 million over four years.
Recoverable energy costs	Current rate recovery of purchased power costs.	Current rate recovery of purchased power costs.
Cost reconciliations	None	None
Average rate base	Yr. 1 – $178.7 million	Yr. 1 – $229.9 million
Weighted average cost of capital (after-tax)	7.47 percent	7.11 percent
Authorized return on common equity	9.6 percent	9.5 percent
Actual return on common equity	Yr. 1 – 7.5 percent Yr. 2 – 5.7 percent	Yr. 1 – 5.4 percent
Cost of long-term debt	5.37 percent	4.88 percent
Common equity ratio	49.7 percent	48.32 percent

(a)In January 2016, the NJBPU approved RECO’s plan to spend $15.7 million in capital over three years to harden its electric system against storms, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge.

In November 2017, FERC approved a September 2017 settlement agreement among RECO, the New Jersey Division of Rate Counsel and the NJBPU that increases RECO's annual transmission revenue requirement from $11.8 million to $17.7 million, effective April 2017. The revenue requirement reflects a return on common equity of 10.0 percent.

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, 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 closed all non-essential businesses statewide. New York State designated utilities, including CECONY and O&R, as essential businesses that were able to continue a portion of their work during the effectiveness of the PAUSE order. In May 2020, the "New York Forward" plan went into effect. New York Forward is a phased plan to reopen businesses in geographic areas of New York State that meet metrics established by various public health organizations. In October 2020, Governor Cuomo announced a new cluster action initiative to address COVID-19 hotspots that have arisen in various areas of New York within the Utilities’ service territory and to impose new rules and restrictions targeted to areas with the highest concentration of COVID-19 cases and the surrounding communities. As a result of these COVID-19 clusters, the Utilities have limited their work in customer premises in the impacted areas to only address emergency, safety-related and selected service connections requested by customers. Since 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 during the COVID-19 state of emergency. In addition, such prohibition will apply for an additional 180 days after the state of emergency ends for residential customers who have experienced a change in financial circumstances due to the COVID-19 pandemic. The law expires on March 31, 2021, although legislation has been introduced to extend the expiration date until December 31, 2021 or later. For the year ended December 31, 2020, the estimated foregone revenues that were not collected by CECONY and O&R were approximately $61 million and $3 million, respectively (see Note M). Also in March 2020, the Utilities requested and the NYSPSC granted extensions to file their 2019 Earnings Adjustment Mechanisms (EAMs) reports, which were filed in July 2020. The earned EAM incentives of approximately $46 million and $3 million for CECONY

and O&R, respectively, are being recovered from customers over a twelve-month period that began September 2020.

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 cost of the program is being recovered over a five-year period that began January 2021. As of December 31, 2020, CECONY deferred for later recovery $63.4 million of summer cooling credit costs.

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. For the year ended December 31, 2020, the reserve increases to the allowance for uncollectible accounts associated with the COVID-19 pandemic for CECONY electric and gas operations and O&R electric operations were $73 million and $2 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. The reserve increase to the allowance for uncollectible accounts associated with the COVID-19 pandemic for O&R gas operations of $1 million did not meet the deferral threshold at December 31, 2020. 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 (due to the New York State on PAUSE and related executive orders), which differences were $18 million and $1 million for CECONY and O&R, respectively, for the year ended December 31, 2020.

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, NYSPSC staff 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 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.

In February 2021, the NYSPSC staff issued its report on New York State’s Energy Affordability Policy that provides recommendations to large New York utilities, including CECONY and O&R. 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 currently expires on March 31, 2021, although legislation has been introduced to extend the expiration to December 31, 2021 or later) 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 NYSPSC staff has requested that the utilities and interested parties comment on the report prior to staff submitting the recommendations to the NYSPSC for consideration.

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

The Utilities’ rate plans have revenue decoupling mechanisms in their New York electric and gas businesses that 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 and O&R New York’s electric customers and after the annual deferral period ends for CECONY 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.

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. Since that declaration, 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 is not expected to be 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 through the later of September 30, 2021, or 60 days after the emergency declaration is no longer in effect. RECO deferred net incremental COVID-19 related costs of $0.5 million through December 31, 2020.

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. See footnote (d) to the CECONY - Electric and Gas tables under “Rate Plans,” above.

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. See "Rate Plans," above.

In January 2018, the NYSPSC issued an order initiating a focused operations audit of the income tax accounting of certain utilities, including CECONY and O&R. The Utilities are unable to estimate the amount or range of their possible loss related to this matter. At December 31, 2020, the Utilities had not accrued a liability related to this matter.

In March 2018, Winter Storms Riley and Quinn caused damage to the Utilities’ electric distribution systems and interrupted service to approximately 209,000 CECONY customers, 93,000 O&R customers and 44,000 RECO customers. At December 31, 2020, CECONY's costs related to March 2018 storms, including Riley and Quinn, amounted to $134 million, including operation and maintenance expenses reflected in its electric rate plan ($15 million), operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan ($84 million), capital expenditures ($29 million) and removal costs ($6 million). At December 31, 2020, O&R and RECO costs related to 2018 storms amounted to $43 million and $17 million, respectively, most of which were deferred as regulatory assets pursuant to their electric rate plans. In January 2019, O&R began recovering its deferred storm costs over a six-year period in accordance with its New York electric rate plan. In February 2020, RECO began recovering its deferred storm costs over a four-year period in accordance with its New Jersey electric

rate plan. The NYSPSC investigated the preparation and response to the storms by CECONY, O&R, and other New York electric utilities, including all aspects of their emergency response plans. In April 2019, following the issuance of a NYSPSC staff report on the investigation, the NYSPSC ordered the utilities to show cause why the NYSPSC should not commence a penalty action against them for violating their emergency response plans. During 2020, CECONY and O&R accrued $5.6 million and $0.85 million, respectively, related to this matter. In August 2020, the NYSPSC approved a July 2020 settlement agreement that provides for the Utilities to set aside $5.6 million and $0.85 million for the benefit of CECONY and O&R electric customers, respectively.

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. The NYSPSC has commenced an investigation. As of December 31, 2019, 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.

In March 2019, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence a penalty action and prudence proceeding against CECONY for alleged violations of gas operator qualification, performance, and inspection requirements. At December 31, 2019, the company had an accrued regulatory liability related to this matter of $10 million, and at March 31, 2020, the company accrued an additional regulatory liability of $5 million. In April 2020, the NYSPSC approved a $15 million settlement agreement for the benefit of CECONY’s gas customers between CECONY and NYSPSC staff related to this matter.

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. CECONY has not accrued any additional liability related to this matter and is unable to determine the outcome of this proceeding at this time.

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 December 31, 2020, CECONY incurred costs for Tropical Storm Isaias of $153 million (including $77 million of operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan, $58 million of capital expenditures and $18 million of operation and maintenance expenses). As of December 31, 2020, O&R incurred costs for Tropical Storm Isaias of $34 million (including $26 million of operation and maintenance expenses charged against a storm reserve pursuant to its New York electric rate plan and $8 million of capital expenditures). 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. In addition, as of December 31, 2020, CECONY and O&R incurred costs of $7.5 million and $2.9 million, respectively, for food and medicine spoilage claims. 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 New York State Department of Public Service (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. The Utilities have not accrued a liability related to this matter and are unable to determine the outcome of this proceeding at this time.

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. The Department of Energy is expected to issue regulations implementing the executive order. In January 2021, the president of the United States suspended the May 2020 executive order for 90 days. The Companies are unable to predict the impact on them of regulations that may be adopted regarding the bulk-power system.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2020 and 2019 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Regulatory assets
Unrecognized pension and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	865	732	791	647
Revenue taxes	356	321	342	308
Pension and other postretirement benefits deferrals	315	71	272	47
Property tax reconciliation	241	219	239	210
Deferred storm costs	195	77	83	—
MTA power reliability deferral	188	248	188	248
System peak reduction and energy efficiency programs	124	131	124	130
Deferred derivative losses	120	83	111	76
COVID - 19 Deferrals	115	—	113	—
Municipal infrastructure support costs	62	75	62	75
Brooklyn Queens demand management program	36	39	36	39
Meadowlands heater odorization project	32	35	32	35
Gate station upgrade project	25	19	25	19
Unamortized loss on reacquired debt	21	28	19	26
Preferred stock redemption	21	22	21	22
Recoverable REV demonstration project costs	20	21	18	19
Non-wire alternative projects	18	14	18	14
Workers’ compensation	—	3	—	3
Other	200	180	186	166
Regulatory assets – noncurrent	6,195	4,859	5,745	4,487
Deferred derivative losses	190	128	177	113
Recoverable energy costs	76	—	67	—
Regulatory assets – current	266	128	244	113
Total Regulatory Assets	$6,461	$4,987	$5,989	$4,600
Regulatory liabilities
Future income tax*	$2,207	$2,426	$2,062	$2,275
Allowance for cost of removal less salvage	1,090	989	932	843
TCJA net benefits	295	471	286	454
Net unbilled revenue deferrals	198	199	198	199
Net proceeds from sale of property	137	173	137	173
Pension and other postretirement benefit deferrals	85	75	46	46
System benefit charge carrying charge	64	48	57	44
Property tax refunds	36	45	35	45
BQDM and REV Demo reconciliations	27	27	25	26
Settlement of gas proceedings	21	10	21	10
Sales and use tax refunds	16	8	16	8
Earnings sharing - electric, gas and steam	15	22	10	15
Unrecognized other postretirement costs	11	9	—	—
Settlement of prudence proceeding	5	8	5	8
Workers’ compensation	3	—	3	—
Energy efficiency portfolio standard unencumbered funds	1	122	—	118
Other	302	195	261	163
Regulatory liabilities – noncurrent	4,513	4,827	4,094	4,427
Refundable energy costs	28	44	4	12
Deferred derivative gains	8	34	7	34
Revenue decoupling mechanism	—	24	—	17
Regulatory liabilities—current	36	102	11	63
Total Regulatory Liabilities	$4,549	$4,929	$4,105	$4,490

* See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.

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

MTA power reliability deferral represents CECONY’s costs in excess of those reflected in its prior electric rate plan to take certain actions relating to the electrical equipment that serves the Metropolitan Transportation Authority (MTA) subway system. The company is recovering this regulatory asset pursuant to its current electric rate plan. See footnote (d) to the CECONY - Electric table under “Rate Plans,” above.

Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Tropical Storm Isaias, Superstorm Sandy and other major storms that were deferred by the Utilities.

Settlement of prudence proceeding represents the remaining amount to be credited to customers pursuant to a Joint Proposal, approved by the NYSPSC in April 2016, with respect to the prudence of certain CECONY expenditures and related matters.

Settlement of gas proceedings represents the amount to be credited to customers pursuant to a settlement agreement approved by the NYSPSC in February 2017 related to CECONY’s practices of qualifying persons to perform plastic fusions on gas facilities and alleged violations of gas safety violations identified by the NYSPSC staff in its investigation of a March 2014 Manhattan explosion and fire (see Note H).

COVID - 19 Deferrals represents both the amount to be collected from customers related to the Emergency Summer Cooling Credits program for CECONY and amounts related to the increase in the allowance for uncollectible accounts resulting from the COVID-19 pandemic and New York on PAUSE and related executive orders, for electric and gas operations for CECONY and electric operations for O&R.

The NYSPSC has authorized CECONY to accrue unbilled electric, gas and steam revenues. CECONY has deferred the net margin on the unbilled revenues for the future benefit of customers by recording a regulatory liability of $198 million and $199 million at December 31, 2020 and 2019, respectively, for the difference between the unbilled revenues and energy cost liabilities.

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.

In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made ($1,696 million and $1,188 million for Con Edison, and $1,509 and $1,054 million for CECONY at December 31, 2020 and 2019, respectively). Regulatory liabilities are treated in a consistent manner. The Other Customer-Provided Capital rate for the years ended December 31, 2020 and 2019 was 2.65 percent and 4.2 percent, respectively. The recognition of the return on regulatory assets is determined by the Utilities’ rate plans or orders issued by state regulators.

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 December 31, 2020 and 2019, 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)	2020	2019	2020	2019
Unrecognized and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	855	727	781	647
Revenue taxes	336	296	323	285
Deferred derivative losses	120	83	111	76
Workers' compensation	—	3	—	3
Other	24	21	24	20
Deferred derivative losses - current	190	128	177	112
Total	4,766	3,799	4,481	3,546

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 represent the 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.

Electricity Purchase Agreements

The Utilities have electricity purchase agreements with non-utility generators and others for generating capacity. The Utilities recover their purchased power costs in accordance with provisions approved by the applicable state public utility regulators. See “Recoverable Energy Costs” in Note A. The Utilities also conducted auctions and have entered into various other electricity purchase agreements. Assuming performance by the parties to the electricity purchase agreements, the Utilities are obligated over the terms of the agreements to make capacity and other fixed payments.

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

(Millions of Dollars)	2021	2022	2023	2024	2025	All Years Thereafter
Con Edison	$141	$106	$68	$53	$54	$487
CECONY	138	106	68	53	54	487

For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the significant terms of the agreements for capacity, energy and other fixed payments in 2020, 2019 and 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Indian Point (a)	$—	$—	$6
Astoria Generating Company (b)	26	116	179
Brooklyn Navy Yard (c)	113	115	124
Cogen Technologies	—	—	9
Total	$139	$231	$318

(a) Contract term ended in 2018.

(b) Capacity purchase agreements with terms ending in 2020 and 2023.

(c) Contract for plant output, which started in 1996 and ends in 2036.

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Capitalization

12 Months Ended

Dec. 31, 2020

Debt Disclosure [Abstract]

Capitalization

Capitalization

Common Stock

Con Edison is authorized to issue 500,000,000 shares of its common stock and CECONY is authorized to issue 340,000,000 of its common stock. At December 31, 2020 and 2019, 342,297,534 and 332,629,597 shares, respectively, of Con Edison common stock were outstanding. At December 31, 2020 and 2019, 235,488,094 million shares of CECONY common stock were outstanding, all of which were owned by Con Edison. At December 31, 2020 and 2019, Con Edison had 23,210,700 treasury shares, including 21,976,200 shares of Con Edison stock that CECONY purchased prior to 2001 in connection with Con Edison’s stock repurchase plan. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity.

In May 2019, Con Edison entered into a forward sale agreement relating to 5,800,000 shares of its common stock. In June 2019, the company issued 4,750,000 shares for $400 million upon physical settlement of shares subject to the forward sale agreement. In January 2020, the company issued 1,050,000 shares for $88 million upon physical settlement of the remaining shares subject to the forward sale agreement.

In December 2020, Con Edison issued 7,200,000 shares of its common stock resulting in net proceeds of approximately $553 million, after issuance expenses. The net proceeds from the sale of the common shares, together with the net proceeds from the sale of $650 million aggregate principal amount of 0.65 percent debentures due 2023, were used to prepay in full a $820 million July 2020 term loan. The remaining net proceeds from the sale of the common shares were invested by Con Edison in its subsidiaries, principally CECONY and O&R, and for other general corporate purposes.

Capitalization of Con Edison

Con Edison's capitalization shown on its Consolidated Statement of Capitalization includes its outstanding common stock and long-term debt and the outstanding long-term debt of the Utilities and the Clean Energy Businesses.

Dividends

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

Long-term Debt

Long-term debt maturing in the period 2021-2025 is as follows:

(Millions of Dollars)	Con Edison	CECONY
2021	$1,967	$640
2022	437	—
2023	966	—
2024	385	250
2025	315	—

CECONY has issued $450 million of tax–exempt debt through the New York State Energy Research and Development Authority (NYSERDA) that currently bear interest at a rate determined weekly and is subject to tender by bondholders for purchase by the company.

The carrying amounts and fair values of long-term debt at December 31, 2020 and 2019 are:

(Millions of Dollars)	2020		2019
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$22,349	$26,808	$19,973	$22,738
CECONY	$16,789	$20,974	$14,964	$17,505

(a)Amounts shown are net of unamortized debt expense and unamortized debt discount of $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020 and $178 million and $151 million for Con Edison and CECONY, respectively, as of December 31, 2019.

The fair values of the Companies' long-term debt have been estimated primarily using available market information and at December 31, 2020 are classified as Level 2 (see Note Q).

Significant Debt Covenants

The significant debt covenants under the financing arrangements for the Companies' debentures and Con Edison's notes and February 2019 $825 million ($675 million of which was outstanding at December 31, 2020) variable-rate term loan that matures in June 2021 include obligations to pay principal and interest when due and covenants not to consolidate with or merge into any other entity unless certain conditions are met. In addition, the notes include a covenant that the company shall continue its utility business in New York City, the term loan includes a covenant that, subject to certain exceptions, the company and its subsidiaries will not mortgage, lien, pledge or otherwise encumber its assets, and the notes and term loan provide that the company shall not permit its ratio of consolidated debt to consolidated total capital to exceed certain amounts (0.675 to 1 for the notes and 0.65 for the term loan) and include cross default provisions with respect to the failure by the company or any material subsidiary to make one or more payments in respect of material financial obligations (in excess of an aggregate $100 million of debt for the notes and $150 million of debt or derivative obligations for the term loan, excluding non-recourse debt) of the company (or any of its material subsidiaries, in the case of the notes) and the occurrence of an event or condition which results in the acceleration of the maturity of any material debt (in excess of an aggregate $100 million for the notes and $150 million for the term loan, not including non-recourse debt) of the company (or any of its material subsidiaries, in the case of the notes) or enables the holders of such debt to accelerate the maturity thereof. The Companies' debentures have no cross default provisions. The tax–exempt financing arrangements of CECONY are subject to covenants for the debentures discussed above and the covenants discussed below. The Companies were in compliance with their significant debt covenants at December 31, 2020.

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

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

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

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Short-Term Borrowing

12 Months Ended

Dec. 31, 2020

Debt Disclosure [Abstract]

Short-Term Borrowing

Short-Term BorrowingIn December 2016, Con Edison and the Utilities entered into a credit agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis. The Credit Agreement, as amended in 2019, expires in December 2023. There is a maximum of $2,250 million of credit available through December 2022 and $2,200 million of credit available from then through December 2023. The full amount is available to CECONY and $1,000 million (subject to increase up to $1,500 million) is available to Con Edison, including up to $1,200 million of letters of credit. The Credit Agreement supports the Companies’ commercial paper programs. The Companies have not borrowed under the Credit Agreement. At December 31, 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 December 31, 2019, Con Edison had $1,692 million of commercial paper outstanding of which $1,137 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2019 was 2.0 percent for both Con Edison and CECONY.

At December 31, 2020 and 2019, no loans were outstanding under the Credit Agreement. An immaterial amount of letters of credit were outstanding under the Credit Agreement as of December 31, 2020 and 2019.

The banks’ commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default for a company include that company exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2020 this ratio was 0.53 to 1 for Con Edison and 0.56 to 1 for CECONY); that company having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, subject to certain exceptions; that company or any of its material subsidiaries failing to make one or more payments in respect of material financial obligations (in excess of an aggregate $150 million of debt or derivative obligations other than non-recourse debt) of that company; the occurrence of an event or condition which results in the acceleration of the maturity of any material debt (in excess of an aggregate $150 million of debt other than non-recourse debt) of that company or enables the holders of such debt to accelerate the maturity thereof; and other customary events of default. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings. The Companies were in compliance with their covenants at December 31, 2020.

In December 2020, a subsidiary of the Clean Energy Businesses borrowed $165 million under a $613 million variable-rate construction loan facility that matures no later than November 2021, (the Construction Loan Facility) and that is secured by and was used to fund construction costs for three of the company’s solar electric production projects. The banks’ commitments under the Construction Loan Facility are subject to certain conditions, including, among other customary conditions, demonstration of construction progress, that there be no event of default and no material adverse effect. The subsidiary of the Clean Energy Businesses was in compliance with its covenants at December 31, 2020.

See Note T for information about short-term borrowing between related parties.

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Pension Benefits

12 Months Ended

Dec. 31, 2020

Retirement Benefits [Abstract]

Pension Benefits

Pension Benefits

Con Edison maintains a tax-qualified, non-contributory pension plan that covers substantially all employees of CECONY, O&R and Con Edison Transmission and certain employees of the Clean Energy Businesses. The plan is designed to comply with the Internal Revenue Code and the Employee Retirement Income Security Act of 1974. Con Edison also maintains additional non–qualified supplemental pension plans.

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit costs for 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Service cost – including administrative expenses	$293	$250	$290	$274	$232	$272
Interest cost on projected benefit obligation	549	601	561	515	564	525
Expected return on plan assets	(1,034)	(988)	(1,033)	(980)	(936)	(979)
Recognition of net actuarial loss	699	518	688	661	492	651
Recognition of prior service credit	(16)	(17)	(17)	(19)	(19)	(19)
TOTAL PERIODIC BENEFIT COST	$491	$364	$489	$451	$333	$450
Cost capitalized	(130)	(108)	(127)	(123)	(102)	(119)
Reconciliation to rate level	(250)	(15)	(92)	(239)	(12)	(100)
Total expense recognized	$111	$241	$270	$89	$219	$231

In March 2017, the FASB issued amendments to the guidance for retirement benefits through ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The Companies adopted ASU 2017-07 beginning on January 1, 2018. The

guidance requires that components of net periodic benefit cost other than service cost be presented outside of operating income on consolidated income statements, and that only the service cost component is eligible for capitalization. Accordingly, the service cost components are 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. In August 2018, the FASB issued amendments to the guidance for retirement benefits through ASU 2018-14, “Compensation-Retirement Benefits (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans." The guidance requires disclosure of the weighted-average interest crediting rate used for cash balance plans for all periods presented, and a narrative description of significant changes in the benefit obligation. The Companies adopted ASU 2018-14 for fiscal years ending after December 15, 2020 and the required disclosures are included below and, as applicable, in Note F.

Funded Status

The funded status at December 31, 2020, 2019 and 2018 was as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$16,792	$14,449	$15,536	$15,750	$13,542	$14,567
Service cost – excluding administrative expenses	288	245	286	269	228	267
Interest cost on projected benefit obligation	549	601	561	515	564	525
Net actuarial loss/(gain)	2,281	2,191	(1,219)	2,154	2,076	(1,159)
Plan amendments	—	15	—	—	—	—
Benefits paid	(945)	(709)	(715)	(867)	(660)	(658)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$18,965	$16,792	$14,449	$17,821	$15,750	$13,542
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$15,608	$13,450	$14,274	$14,790	$12,744	$13,519
Actual return on plan assets	1,927	2,556	(536)	1,830	2,425	(507)
Employer contributions	475	350	473	435	318	434
Benefits paid	(945)	(709)	(715)	(867)	(660)	(658)
Administrative expenses	(43)	(39)	(46)	(41)	(37)	(44)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$17,022	$15,608	$13,450	$16,147	$14,790	$12,744
FUNDED STATUS	$(1,943)	$(1,184)	$(999)	$(1,674)	$(960)	$(798)
Unrecognized net loss	$3,330	$2,604	$2,464	$3,145	$2,466	$2,338
Unrecognized prior service costs/(credits)	(156)	(173)	(205)	(183)	(202)	(222)
Accumulated benefit obligation	16,768	15,015	13,030	15,676	14,010	12,161

The increase in the pension funded status liability at December 31, 2020 for Con Edison and CECONY of $759 million and $714 million, respectively, compared with December 31, 2019, was primarily due to an increase in the plan's projected benefit obligation as a result of a decrease in the discount rate. The increase in the pension funded status liability at December 31, 2019 for Con Edison and CECONY of $185 million and $162 million, respectively, compared with December 31, 2018, was primarily due to an increase in the plan’s projected benefit obligation as a result of a decrease in the discount rate, partially offset by an increase in plan assets as a result of the actual return on plan assets. See below for further information on the change in the discount rate and determination of the discount rate assumption. For Con Edison, the 2020 increase in pension funded status liability corresponds with an increase to regulatory assets of $734 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, a debit to OCI of $8 million (net of taxes) for the unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of the Clean Energy Businesses, Con Edison Transmission, and RECO who previously worked for the Utilities.

For CECONY, the increase in the pension funded status liability at December 31, 2020 corresponds with an increase to regulatory assets of $696 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, and also a debit to OCI of $2 million (net of taxes) for unrecognized net losses, and an immaterial change to OCI (net of taxes) for the unrecognized prior service costs associated with certain employees of the Clean Energy Businesses and Con Edison Transmission who previously worked for CECONY.

At December 31, 2020 and 2019, Con Edison’s investments included $465 million and $397 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $439 million and $371 million, respectively. See Note Q. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $414 million and $377 million as of December 31, 2020, respectively, and $395 million and $360 million as of December 31, 2019, respectively.

Assumptions

The actuarial assumptions were as follows: 

	2020		2019		2018
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate	2.55	%	3.35	%	4.25	%
Interest crediting rate for cash balance plan	3.00	%	3.30	%	4.00	%
Rate of compensation increase
CECONY	3.80	%	3.80	%	4.25	%
O&R	3.20	%	3.20	%	4.00	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	3.35	%	4.25	%	3.70	%
Interest crediting rate for cash balance plan	3.30	%	4.00	%	4.10	%
Expected return on plan assets	7.00	%	7.00	%	7.50	%
Rate of compensation increase
CECONY	3.80	%	4.25	%	4.25	%
O&R	3.20	%	4.00	%	4.00	%

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

Discount Rate Assumption

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

Expected Benefit Payments

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

(Millions of Dollars)	2021	2022	2023	2024	2025	2026-2030
Con Edison	$764	$776	$793	$807	$821	$4,295
CECONY	706	718	733	747	760	3,992

Expected Contributions

Based on estimates as of December 31, 2020, the Companies expect to make contributions to the pension plans during 2021 of $480 million (of which $441 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.

Plan Assets

The asset allocations for the pension plan at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2021	2020		2019		2018
Equity Securities	45% - 55%	51	%	51	%	51	%
Debt Securities	33% - 43%	38	%	38	%	39	%
Real Estate	10% - 14%	11	%	11	%	10	%
Total	100%	100	%	100	%	100	%

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

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

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

The strategic asset allocation is intended to meet the objectives of the pension plan by diversifying its funds across asset classes, investment styles and fund managers. An asset/liability study typically is conducted every few years to determine whether the current strategic asset allocation continues to represent the appropriate balance of expected risk and reward for the plan to meet expected liabilities. Each study considers the investment risk of the asset allocation and determines the optimal asset allocation for the plan. The target asset allocation for 2021 reflects the results of such a study conducted in 2018.

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

Assets measured at fair value on a recurring basis are summarized below as defined by the accounting rules for fair value measurements (see Note Q).

The fair values of the pension plan assets at December 31, 2020 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Investments within the fair value hierarchy
U.S. Equity (a)	$4,202	$—	$4,202
International Equity (b)	3,693	—	3,693
U.S. Government Issued Debt (c)	—	1,424	1,424
Corporate Bonds Debt (d)	—	3,535	3,535
Structured Assets Debt (e)	—	188	188
Other Fixed Income Debt (f)	—	1,067	1,067
Cash and Cash Equivalents (g)	51	408	459
Total investments within the fair value hierarchy	$7,946	$6,622	$14,568
Investments measured at NAV per share (m)
Private Equity (h)			635
Real Estate (i)			1,880
Hedge Funds (j)			292
Total investments valued using NAV per share			$2,807
Funds for retiree health benefits (k)	(116)	(97)	(213)
Funds for retiree health benefits measured at NAV per share (k)(m)			(41)
Total funds for retiree health benefits			$(254)
Investments (excluding funds for retiree health benefits)	$7,830	$6,525	$17,121
Pending activities (l)			(99)
Total fair value of plan net assets			$17,022

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

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

(c)U.S. Government Issued Debt includes agency and treasury securities.

(d)Corporate Bonds Debt consists of debt issued by various corporations.

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

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

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

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

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

(j)Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.

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

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

(m)In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy.

The fair values of the pension plan assets at December 31, 2019 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,652	$—	$3,652
International Equity (b)	3,354	—	3,354
U.S. Government Issued Debt (c)	—	1,496	1,496
Corporate Bonds Debt (d)	—	3,260	3,260
Structured Assets Debt (e)	—	173	173
Other Fixed Income Debt (f)	—	955	955
Cash and Cash Equivalents (g)	—	326	326
Total investments within the fair value hierarchy	$7,006	$6,210	$13,216
Investments measured at NAV per share (m)
Private Equity (h)			555
Real Estate (i)			1,806
Hedge Funds (j)			270
Total investments valued using NAV per share			$2,631
Funds for retiree health benefits (k)	(110)	(98)	(208)
Funds for retiree health benefits measured at NAV per share (k)(m)			(42)
Total funds for retiree health benefits			$(250)
Investments (excluding funds for retiree health benefits)	$6,896	$6,112	$15,597
Pending activities (l)			11
Total fair value of plan net assets			$15,608

(a) - (m) Reference is made to footnotes (a) through (m) in the above table of pension plan assets at December 31, 2020 by asset category.

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

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$52	$49	$45
CECONY	43	42	39

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Other Postretirement Benefits

12 Months Ended

Dec. 31, 2020

Retirement Benefits [Abstract]

Other Postretirement Benefits

Other Postretirement Benefits

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

CECONY also has a contributory life insurance program for bargaining unit employees and provides basic life insurance benefits up to a specified maximum at no cost to certain retired management employees. O&R has a non-contributory life insurance program for retirees. Certain employees of the Clean Energy Businesses and Con Edison Transmission are eligible to receive benefits under these programs.

Total Periodic Benefit Cost

The components of the Companies’ total periodic postretirement benefit costs for 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Service cost	$21	$18	$20	$16	$13	$14
Interest cost on accumulated other postretirement benefit obligation	37	44	42	31	36	34
Expected return on plan assets	(66)	(66)	(73)	(54)	(54)	(63)
Recognition of net actuarial loss/(gain)	37	(9)	8	36	(10)	3
Recognition of prior service credit	(3)	(2)	(6)	(2)	(2)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	$26	$(15)	$(9)	$27	$(17)	$(14)
Cost capitalized	(9)	(7)	(8)	(7)	(5)	(6)
Reconciliation to rate level	(17)	12	8	(25)	7	9
Total credit recognized	$—	$(10)	($9)	$(5)	$(15)	($11)

For information about the adoption of ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” and ASU 2018-14, “Compensation-Retirement Benefits (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit Plans," see Note E.

Funded Status

The funded status of the programs at December 31, 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$1,357	$1,114	$1,219	$1,154	$913	$985
Service cost	21	18	20	16	13	14
Interest cost on accumulated postretirement benefit obligation	37	44	42	31	36	34
Amendments	—	(14)	—	—	—	—
Net actuarial loss/(gain)	74	264	(70)	63	252	(32)
Benefits paid and administrative expenses, net of subsidies	(117)	(110)	(135)	(107)	(100)	(125)
Participant contributions	53	41	38	52	40	37
BENEFIT OBLIGATION AT END OF YEAR	$1,425	$1,357	$1,114	$1,209	$1,154	$913
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$1,026	$885	$1,039	$872	$759	$893
Actual return on plan assets	142	198	(66)	117	165	(54)
Employer contributions	7	7	6	4	6	6
Employer group waiver plan subsidies	20	23	34	19	22	32
Participant contributions	53	40	37	51	40	37
Benefits paid	(133)	(127)	(165)	(123)	(120)	(155)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$1,115	$1,026	$885	$940	$872	$759
FUNDED STATUS	$(310)	$(331)	$(229)	$(269)	$(282)	$(154)
Unrecognized net loss/(gain)	$115	$155	$14	$114	$149	$(2)
Unrecognized prior service costs	(16)	(19)	(8)	(1)	(3)	(5)

The decrease in the other postretirement benefits funded status liability at December 31, 2020 for Con Edison and CECONY of $21 million and $13 million, respectively, compared with December 31, 2019, was primarily due to an increase in the fair value of plan assets as a result of the actual return on plan assets, partially offset by an increase in the plans' projected benefit obligation as a result of a decrease in the discount rate. See below for further information on the change in the discount rate and see Note E for determination of the discount rate assumption. The increase in the other postretirement benefits funded status liability at December 31, 2019 for Con Edison and CECONY of $102 million and $128 million, respectively, compared with December 31, 2018, was primarily due to an

increase in the plans' projected benefit obligation as a result of an increase in net actuarial loss, partially offset by an increase in plan assets as a result of the actual return on plan assets.

For Con Edison, the decrease in funded status liability at December 31, 2020 corresponds with a net decrease to regulatory assets of $36 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, a credit to OCI of $2 million (net of taxes) for the unrecognized net losses and an immaterial change to OCI for the unrecognized prior service costs associated with the Clean Energy Businesses, Con Edison Transmission, and RECO.

For CECONY, the decrease in funded status liability at December 31, 2020 corresponds with a decrease to regulatory assets of $33 million for unrecognized net losses and the unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, and immaterial changes to OCI for the unrecognized net losses and the unrecognized prior service costs associated with eligible employees of the Clean Energy Businesses and Con Edison Transmission who previously worked for CECONY.

Assumptions

The actuarial assumptions were as follows: 

	2020		2019		2018
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY	2.25	%	3.10	%	4.15	%
O&R	2.55	%	3.35	%	4.30	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate
CECONY	3.10	%	4.15	%	3.55	%
O&R	3.35	%	4.30	%	3.70	%
Expected Return on Plan Assets	6.80	%	6.80	%	7.50	%

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

The health care cost trend rate used to determine net periodic benefit cost for the years ended December 31, 2020, 2019 and 2018 was 5.20 percent, 5.40 percent and 5.60 percent, respectively, which was assumed to decrease gradually to 4.50 percent by 2024 and remain at that level thereafter. The health care cost trend rate used to determine benefit obligations as of December 31, 2020, 2019 and 2018 was 7.04 percent, 5.20 percent and 5.40 percent, respectively, which is assumed to decrease gradually to 4.50 percent by 2034 and remain at that level thereafter.

Expected Benefit Payments

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

(Millions of Dollars)	2021	2022	2023	2024	2025	2026-2030
Con Edison	$84	$84	$84	$84	$84	$409
CECONY	76	75	75	75	75	358

Expected Contributions

Based on estimates as of December 31, 2020, Con Edison and CECONY expect to make a contribution of $6 million (of which $3 million is expected to be made by CECONY) to the other postretirement benefit plans in 2021. The Companies’ policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

Plan Assets

The asset allocations for CECONY’s other postretirement benefit plans at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2021	2020		2019		2018
Equity Securities	42%-80%	54	%	54	%	52	%
Debt Securities	20%-58%	46	%	46	%	48	%
Total	100%	100	%	100	%	100	%

Con Edison has established postretirement health and life insurance benefit plan trusts for the investment of assets to be used for the exclusive purpose of providing other postretirement benefits to participants and beneficiaries.

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

The fair values of the plans' assets at December 31, 2020 by asset category as defined by the accounting rules for fair value measurements (see Note Q) are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Equity (a)	$—	$448	$448
Other Fixed Income Debt (b)	—	367	367
Cash and Cash Equivalents (c)	—	27	27
Total investments	$—	$842	$842
Funds for retiree health benefits (d)	116	97	213
Investments (including funds for retiree health benefits)	$116	$939	$1,055
Funds for retiree health benefits measured at net asset value (d)(e)			41
Pending activities (f)			19
Total fair value of plan net assets			$1,115

(a)Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index.

(b)Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index.

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

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

(e)In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy.

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

The fair values of the plans' assets at December 31, 2019 by asset category (see Note Q) are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Equity (a)	$—	$404	$404
Other Fixed Income Debt (b)	—	331	331
Cash and Cash Equivalents (c)	—	23	23
Total investments	$—	$758	$758
Funds for retiree health benefits (d)	110	98	208
Investments (including funds for retiree health benefits)	$110	$856	$966
Funds for retiree health benefits measured at net asset value (d)(e)			42
Pending activities (f)			18
Total fair value of plan net assets			$1,026

(a) - (f) Reference is made to footnotes (a) through (f) in the above table of other postretirement benefit plan assets at December 31, 2020 by asset category.

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Environmental Matters

12 Months Ended

Dec. 31, 2020

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 December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Accrued Liabilities:
Manufactured gas plant sites	$752	$640	$676	$561
Other Superfund Sites	105	94	104	93
Total	$857	$734	$780	$654
Regulatory assets	$865	$732	$791	$647

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 at December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Remediation costs incurred	$33	$19	$32	$13

Insurance and other third party recoveries received by Con Edison or CECONY were immaterial in 2020 and 2019.

Con Edison and CECONY estimate that in 2021 they will incur costs for remediation of approximately $40 million and $38 million, respectively. The Companies are unable to estimate the time period over which the remaining accrued liability will be incurred because, among other things, the required remediation has not been determined for some of the sites.

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 $2,700 million and $2,600 million, 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 December 31, 2020, Con Edison and CECONY have accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. These estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Courts have begun, and unless otherwise determined on appeal may continue, to apply different standards for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims.

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$72	$78	$68	$73
Regulatory assets/(liabilities) – workers’ compensation	$(3)	$3	$(3)	$3

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Material Contingencies

12 Months Ended

Dec. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Material Contingencies

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 October 2020, the company accrued a $40 million liability for damages and a $40 million insurance receivable related to the incident.

For information about material contingencies, see “Other Regulatory Matters” in Note B, “Superfund Sites” and “Asbestos Proceedings” in Note G and "Uncertain Tax Positions" in Note L.

Con Edison and its subsidiaries have entered into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison under these agreements totaled $2,042 million and $1,831 million at December 31, 2020 and 2019, respectively.

A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2020 is as follows:

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years	Total
	(Millions of Dollars)
Con Edison Transmission	$393	$177	$—	$570
Energy transactions	480	51	222	753
Renewable electric production projects	285	9	355	649
Other	70	—	—	70
Total	$1,228	$237	$577	$2,042

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.

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 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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Electricity Purchase Agreements

12 Months Ended

Dec. 31, 2020

Regulated Operations [Abstract]

Electricity Purchase Agreements

Regulatory Matters

Rate Plans

The Utilities provide service to New York customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary, are approved by the NJBPU. The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator.

Common provisions of the Utilities’ New York rate plans include:

Recoverable energy costs that allow the Utilities to recover on a current basis the costs for the energy they supply with no mark-up to their full-service customers.

Cost reconciliations that reconcile pension and other postretirement benefit costs, environmental remediation costs, property taxes, variable-rate tax-exempt debt and certain other costs to amounts reflected in delivery rates for such costs. In addition, changes in the Utilities' costs not reflected in rates, in excess of certain amounts, resulting from changes in tax or changes in legislation, regulation or related actions, are deferred as a regulatory asset or regulatory liability to be reflected in the Utilities' next rate plan or in a manner to be determined by the NYSPSC. Also, the Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases and provision is sometimes made for the utility to retain a share of cost reductions, for example, property tax refunds.

Revenue decoupling mechanisms that reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC. The difference is accrued with interest for refund to, or recovery from customers, as applicable.

Earnings sharing that require the Utilities to defer for customer benefit a portion of earnings over specified rates of return on common equity. There is no symmetric mechanism for earnings below specified rates of return on common equity.

Negative revenue adjustments for failure to meet certain performance standards relating to service, reliability, safety and other matters.

Positive revenue adjustments for achievement of performance standards related to achievement of clean energy goals, safety and other matters.

Net utility plant reconciliations that require deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates. There is generally no symmetric mechanism if actual average net utility plant balances are more than amounts reflected in rates.

Rate base, as reflected in the rate plans, is, in general, the sum of the Utilities’ net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. For each rate plan, the NYSPSC uses a forecast of the average rate base for each year that new rates would be in effect (“rate year”). 

Weighted average cost of capital is determined based on the authorized common equity ratio, return on common equity, cost of long-term debt and cost of customer deposits reflected in each rate plan. For each rate plan, the revenues designed to provide the utility a return on invested capital for each rate year are determined by multiplying each utility rate base by its pre–tax weighted average cost of capital. The Utilities’ actual return on common equity will reflect their actual operations for each rate year, and may be more or less than the authorized return on equity reflected in their rate plans (and if more, may be subject to earnings sharing).

The following tables contain a summary of the Utilities’ rate plans:

CECONY – Electric
Effective period	January 2017 – December 2019	January 2020 – December 2022 (a)
Base rate changes	Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b)	Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million	Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d)
Other revenue sources	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively.	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020, the company recorded $34 million primarily related to earnings adjustment mechanism incentives for energy efficiency.
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, the company deferred for recovery from customers $242 million of revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel 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 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million.	Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively.	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2020, the company deferred $288 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively.	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020.
Average rate base	Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million	Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent	6.61 percent
Authorized return on common equity	9.0 percent	8.80 percent

Actual return on common equity (i)	Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent	Yr. 1 – 8.50 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold.	Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, the company had no earnings sharing above the threshold.
Cost of long-term debt	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent	4.63 percent
Common equity ratio	48 percent	48 percent

(a)In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note T) are not necessary.

(b)The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs.

(c)Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d)Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually).

(e)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.

(f)In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of

30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan.

(g)In addition, the NYSPSC staff has commenced a focused operations audit to investigate the income tax accounting of CECONY and other New York utilities. Any NYSPSC-ordered adjustment to CECONY’s income tax accounting will be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below.

(h)Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas.

(i)Calculated in accordance with the earnings calculation method prescribed in the rate order.

CECONY – Gas
Effective period	January 2017 - December 2019	January 2020 – December 2022 (a)
Base rate changes	Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million	Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million	Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d)
Other revenue sources	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations.	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020, the company recorded $3 million of earnings adjustment mechanism incentives for energy efficiency. In 2020, the company recorded positive incentives of $13 million.
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, the company deferred for recovery from customers $27 million of revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas 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 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any negative revenue adjustments.	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $81 million Yr. 2 - $88 million Yr. 3 - $96 million In 2020, the company did not record any negative revenue adjustments.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively.	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2020, the company deferred $91 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability.	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $8,108 million Yr. 2 - $8,808 million Yr. 3 - $9,510 million AMI: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020, the company deferred $24.7 million as a regulatory liability.
Average rate base	Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million	Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent	6.61 percent
Authorized return on common equity	9.0 percent	8.80 percent
Actual return on common equity (i)	Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent	Yr. 1 – 8.40 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold.	Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent	4.63 percent
Common equity ratio	48 percent	48 percent

(a)In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note T) are not necessary.

(b)The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(c)The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d)Amounts reflect amortization of the remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually)

(e)-(i)    See footnotes (e) - (i) to the table under “CECONY Electric,” above.

CECONY – Steam
Effective period	January 2014 – December 2016 (a)
Base rate changes	Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None
Amortizations to income of net regulatory (assets) and liabilities	$37 million over three years
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2020, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015, 2016, 2017, 2018, 2019 and 2020, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities and $35 million of net regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020.
Average rate base	Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent
Authorized return on common equity	9.3 percent
Actual return on common equity (d)	Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent
Earnings sharing	Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent
Common equity ratio	48 percent

(a)Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC.

(b)The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016.

(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 10 basis point impact on return on common equity.

(d)Calculated in accordance with the earnings calculation method prescribed in the rate order.

O&R New York – Electric
Effective period	November 2015 - October 2017 (a)	January 2019 – December 2021 (d)
Base rate changes	Yr. 1 – $9.3 million Yr. 2 – $8.8 million Yr. 3 – None	Yr. 1 – $13.4 million (e) Yr. 2 – $8.0 million (e) Yr. 3 – $5.8 million (e)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $(8.5) million (b) Yr. 2 – $(9.4) million (b) Yr. 3 – None	Yr. 1 – $(1.5) million (f) Yr. 2 – $(1.5) million (f) Yr. 3 – $(1.5) million (f)
Other revenue sources		Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019 and 2020, the company recorded $2.6 million and $1.9 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively.
Revenue decoupling mechanisms	In 2015, 2016, 2017 and 2018, the company deferred for the customer’s benefit an immaterial amount, $6.3 million as regulatory liabilities, $11.2 million as regulatory asset and $0.5 million as regulatory asset, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million as regulatory assets.
Recoverable energy costs	Continuation of current rate recovery of purchased power costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential charges (up to $4 million annually) if certain performance targets are not met. In 2015 the company recorded $1.25 million in negative revenue adjustments. In 2016, 2017 and 2018, the company did not record any negative revenue adjustments.	Potential charges if certain performance targets relating to service, reliability and other matters are not met: Yr. 1 - $4.4 million Yr. 2 - $4.4 million Yr. 3 - $4.5 million In 2019 and 2020, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2015, 2016 and 2017, the company deferred $0.3 million, $7.4 million and $3.2 million as net decreases to regulatory assets, respectively. In 2018, the company deferred $5 million as a net regulatory asset.	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), major storms, the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $4.3 million and $30.3 million as net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates are: Yr. 1 – $928 million (c) Yr. 2 – $970 million (c) The company increased/(reduced) its regulatory asset by $2.2 million, $(1.9) million, $(1.9) million and $1.4 million in 2015, 2016, 2017 and 2018, respectively.	Target levels reflected in rates were: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $1,008 million Yr. 2 - $1,032 million Yr. 3 - $1,083 million AMI (j): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019 and deferred $0.4 million as a regulatory liability in 2020.
Average rate base	Yr. 1 – $763 million Yr. 2 – $805 million Yr. 3 – $805 million	Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent	Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent
Authorized return on common equity	9.0 percent	9.0 percent
Actual return on common equity (k)	Yr. 1 – 10.8 percent Yr. 2 – 9.7 percent Yr. 3 – 7.2 percent	Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $6.1 million, $0.3 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold.
Cost of long-term debt	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent	Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent
Common equity ratio	48 percent	48 percent

(a)Rates determined pursuant to this rate plan continued in effect until the subsequent rate plan became effective.

(b)$59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a 5 year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015.

(c)Excludes electric AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2.

(d)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 (see Note T) are not necessary.

(e)The electric base rate increases shown above will be implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million.

(f)Reflects amortization of, among other things, the company’s net benefits under the TCJA prior to January 1, 2019, amortization of net regulatory liability for future income taxes and reduction of previously incurred regulatory assets for environmental remediation costs. Also, for electric, reflects amortization over a six year period of previously incurred incremental major storm costs. See "Other Regulatory Matters," below.

(g)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.

(h)Energy efficiency costs are expensed as incurred. Such costs are subject to a downward-only reconciliation over the terms of the electric and gas rate plans. The company will defer for the benefit of customers any cumulative shortfall over the terms of the electric and gas rate plans between actual expenditures and the levels provided in rates.

(i)In addition, amounts reflected in rates relating to income taxes and excess deferred federal income tax liability balances will be reconciled (i.e., refunded to or collected from customers) to any final, non-appealable NYSPSC-ordered findings in its investigation of O&R’s income tax accounting. See “Other Regulatory Matters,” in Note B.

(j)Net plant reconciliation for AMI expenditures will be implemented for a single category of AMI capital expenditures that includes amounts allocated to both electric and gas customers.

(k)Calculated in accordance with the earnings calculation method prescribed in the rate order.

In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective January 1, 2022, of $24.5 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased power, and the reconciliation of actual expenses allocable to the electric business to the amounts for such costs reflected in electric rates for storm costs, pension and other postretirement benefit costs, environmental remediation and property taxes.

O&R New York – Gas
Effective period	November 2015 – October 2018 (a)	January 2019 – December 2021 (d)
Base rate changes	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge	Yr. 1 – $(7.5) million (e) Yr. 2 – $3.6 million (e) Yr. 3 – $0.7 million (e)
Amortization to income of net regulatory (assets) and liabilities	Yr. 1 – $(1.7) million (b) Yr. 2 – $(2.1) million (b) Yr. 3 – $(2.5) million (b)	Yr. 1 – $1.8 million (f) Yr. 2 – $1.8 million (f) Yr. 3 – $1.8 million (f)
Other revenue sources		Continuation of retention of annual revenues from non-firm customers of up to $4.0 million, with variances to be shared 80 percent by customers and 20 percent by company. Potential earnings adjustment mechanism incentives of up to $0.3 million annually. Potential incentives if performance targets related to gas leak backlog, leak prone pipe, emergency response, damage prevention and customer service are met: Yr. 1 - $1.2 million; Yr. 2 - $1.3 million; and Yr. 3 - $1.3 million. In 2019 and 2020, the company recorded $0.3 million of earnings adjustment mechanism incentives for energy efficiency. In 2019 and 2020, the company recorded $0.7 million and $0.5 million of positive incentives, respectively.
Revenue decoupling mechanisms	In 2015, 2016, 2017 and 2018, the company deferred $0.8 million of regulatory assets, $6.2 million of regulatory liabilities, $1.7 million of regulatory liabilities and $6.3 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2019 and 2020, the company deferred $0.8 million and $0.5 million of regulatory assets, respectively.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential charges (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $4.9 million in Yr. 3) if certain performance targets are not met. In 2015, 2016 and 2017, the company did not record any negative revenue adjustments. In 2018, the company recorded a $0.1 million negative revenue adjustment.	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $5.5 million; Yr. 2 - $5.7 million; and Yr. 3 - $6.0 million. In 2019 and 2020, the company recorded a $0.2 million and an immaterial amount of negative revenue adjustments, respectively.
Cost reconciliations	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively. In 2017 and 2018, the company deferred $3.5 million and $7.4 million as net regulatory liabilities, respectively.	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $6 million as net regulatory liabilities and $1.8 million as net regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates are: Yr. 1 – $492 million (c) Yr. 2 – $518 million (c) Yr. 3 – $546 million (c) No deferral was recorded for 2015 and immaterial amounts were recorded as regulatory liabilities in 2016 and 2017. In 2018, the company deferred $0.4 million as regulatory asset.	Target levels reflected in rates were: Gas average net plant target excluding AMI: Yr. 1 - $593 million Yr. 2 - $611 million Yr. 3 - $632 million AMI (j): Yr. 1 - $20 million Yr. 2 - $24 million Yr. 3 - $25 million In 2019 and 2020, the company deferred immaterial amounts as regulatory assets.
Average rate base	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million	Yr. 1 – $454 million Yr. 2 – $476 million Yr. 3 – $498 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent	Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent
Authorized return on common equity	9.0 percent	9.0 percent
Actual return on common equity (k)	Yr. 1 – 11.2 percent Yr. 2 – 9.7 percent Yr. 3 – 8.1 percent	Yr. 1 – 8.90 percent Yr. 2 – 9.58 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million, $0.2 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold.
Cost of long-term debt	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent	Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent
Common equity ratio	48 percent	48 percent

(a)Rates pursuant to this rate plan continued in effect until the subsequent rate plan became effective.

(b)Reflects that the company will not recover from customers a total of approximately $14 million of regulatory assets for property tax and interest rate reconciliations. Amounts that will not be recovered from customers were charged-off in June 2015.

(c)Excludes gas AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $0.5 million in year 1, $4.2 million in year 2 and $7.2 million in year 3.

(d)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 (see Note T) are not necessary.

(e)The gas base rate changes shown above will be implemented with changes of: Yr. 1 - $(5.9) million; Yr. 2 - $1.0 million; and Yr. 3 - $1.0 million.

(f)-(k) See footnotes (f) - (k) to the table under “O&R New York - Electric,” above.

In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for gas service rendered in New York, effective January 1, 2022, of $9.8 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased gas, and the reconciliation of actual expenses allocable to the gas business to the amounts for such costs reflected in gas rates for pension and other postretirement benefit costs, environmental remediation and property taxes.

In January 2020, the NJBPU approved an electric rate increase, effective February 1, 2020, of $12 million for RECO. The following table contains a summary of the terms of the distribution rate plans.

RECO
Effective period	March 2017 – January 2020	February 2020
Base rate changes	Yr. 1 – $1.7 million	Yr. 1 – $12 million
Amortization to income of net regulatory (assets) and liabilities	$0.2 million over three years and continuation of $(25.6) million of deferred storm costs over four years which expired on July 31, 2018 (a)	$4.8 million over four years.
Recoverable energy costs	Current rate recovery of purchased power costs.	Current rate recovery of purchased power costs.
Cost reconciliations	None	None
Average rate base	Yr. 1 – $178.7 million	Yr. 1 – $229.9 million
Weighted average cost of capital (after-tax)	7.47 percent	7.11 percent
Authorized return on common equity	9.6 percent	9.5 percent
Actual return on common equity	Yr. 1 – 7.5 percent Yr. 2 – 5.7 percent	Yr. 1 – 5.4 percent
Cost of long-term debt	5.37 percent	4.88 percent
Common equity ratio	49.7 percent	48.32 percent

(a)In January 2016, the NJBPU approved RECO’s plan to spend $15.7 million in capital over three years to harden its electric system against storms, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge.

In November 2017, FERC approved a September 2017 settlement agreement among RECO, the New Jersey Division of Rate Counsel and the NJBPU that increases RECO's annual transmission revenue requirement from $11.8 million to $17.7 million, effective April 2017. The revenue requirement reflects a return on common equity of 10.0 percent.

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, 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 closed all non-essential businesses statewide. New York State designated utilities, including CECONY and O&R, as essential businesses that were able to continue a portion of their work during the effectiveness of the PAUSE order. In May 2020, the "New York Forward" plan went into effect. New York Forward is a phased plan to reopen businesses in geographic areas of New York State that meet metrics established by various public health organizations. In October 2020, Governor Cuomo announced a new cluster action initiative to address COVID-19 hotspots that have arisen in various areas of New York within the Utilities’ service territory and to impose new rules and restrictions targeted to areas with the highest concentration of COVID-19 cases and the surrounding communities. As a result of these COVID-19 clusters, the Utilities have limited their work in customer premises in the impacted areas to only address emergency, safety-related and selected service connections requested by customers. Since 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 during the COVID-19 state of emergency. In addition, such prohibition will apply for an additional 180 days after the state of emergency ends for residential customers who have experienced a change in financial circumstances due to the COVID-19 pandemic. The law expires on March 31, 2021, although legislation has been introduced to extend the expiration date until December 31, 2021 or later. For the year ended December 31, 2020, the estimated foregone revenues that were not collected by CECONY and O&R were approximately $61 million and $3 million, respectively (see Note M). Also in March 2020, the Utilities requested and the NYSPSC granted extensions to file their 2019 Earnings Adjustment Mechanisms (EAMs) reports, which were filed in July 2020. The earned EAM incentives of approximately $46 million and $3 million for CECONY

and O&R, respectively, are being recovered from customers over a twelve-month period that began September 2020.

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 cost of the program is being recovered over a five-year period that began January 2021. As of December 31, 2020, CECONY deferred for later recovery $63.4 million of summer cooling credit costs.

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. For the year ended December 31, 2020, the reserve increases to the allowance for uncollectible accounts associated with the COVID-19 pandemic for CECONY electric and gas operations and O&R electric operations were $73 million and $2 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. The reserve increase to the allowance for uncollectible accounts associated with the COVID-19 pandemic for O&R gas operations of $1 million did not meet the deferral threshold at December 31, 2020. 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 (due to the New York State on PAUSE and related executive orders), which differences were $18 million and $1 million for CECONY and O&R, respectively, for the year ended December 31, 2020.

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, NYSPSC staff 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 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.

In February 2021, the NYSPSC staff issued its report on New York State’s Energy Affordability Policy that provides recommendations to large New York utilities, including CECONY and O&R. 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 currently expires on March 31, 2021, although legislation has been introduced to extend the expiration to December 31, 2021 or later) 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 NYSPSC staff has requested that the utilities and interested parties comment on the report prior to staff submitting the recommendations to the NYSPSC for consideration.

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

The Utilities’ rate plans have revenue decoupling mechanisms in their New York electric and gas businesses that 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 and O&R New York’s electric customers and after the annual deferral period ends for CECONY 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.

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. Since that declaration, 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 is not expected to be 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 through the later of September 30, 2021, or 60 days after the emergency declaration is no longer in effect. RECO deferred net incremental COVID-19 related costs of $0.5 million through December 31, 2020.

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. See footnote (d) to the CECONY - Electric and Gas tables under “Rate Plans,” above.

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. See "Rate Plans," above.

In January 2018, the NYSPSC issued an order initiating a focused operations audit of the income tax accounting of certain utilities, including CECONY and O&R. The Utilities are unable to estimate the amount or range of their possible loss related to this matter. At December 31, 2020, the Utilities had not accrued a liability related to this matter.

In March 2018, Winter Storms Riley and Quinn caused damage to the Utilities’ electric distribution systems and interrupted service to approximately 209,000 CECONY customers, 93,000 O&R customers and 44,000 RECO customers. At December 31, 2020, CECONY's costs related to March 2018 storms, including Riley and Quinn, amounted to $134 million, including operation and maintenance expenses reflected in its electric rate plan ($15 million), operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan ($84 million), capital expenditures ($29 million) and removal costs ($6 million). At December 31, 2020, O&R and RECO costs related to 2018 storms amounted to $43 million and $17 million, respectively, most of which were deferred as regulatory assets pursuant to their electric rate plans. In January 2019, O&R began recovering its deferred storm costs over a six-year period in accordance with its New York electric rate plan. In February 2020, RECO began recovering its deferred storm costs over a four-year period in accordance with its New Jersey electric

rate plan. The NYSPSC investigated the preparation and response to the storms by CECONY, O&R, and other New York electric utilities, including all aspects of their emergency response plans. In April 2019, following the issuance of a NYSPSC staff report on the investigation, the NYSPSC ordered the utilities to show cause why the NYSPSC should not commence a penalty action against them for violating their emergency response plans. During 2020, CECONY and O&R accrued $5.6 million and $0.85 million, respectively, related to this matter. In August 2020, the NYSPSC approved a July 2020 settlement agreement that provides for the Utilities to set aside $5.6 million and $0.85 million for the benefit of CECONY and O&R electric customers, respectively.

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. The NYSPSC has commenced an investigation. As of December 31, 2019, 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.

In March 2019, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence a penalty action and prudence proceeding against CECONY for alleged violations of gas operator qualification, performance, and inspection requirements. At December 31, 2019, the company had an accrued regulatory liability related to this matter of $10 million, and at March 31, 2020, the company accrued an additional regulatory liability of $5 million. In April 2020, the NYSPSC approved a $15 million settlement agreement for the benefit of CECONY’s gas customers between CECONY and NYSPSC staff related to this matter.

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. CECONY has not accrued any additional liability related to this matter and is unable to determine the outcome of this proceeding at this time.

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 December 31, 2020, CECONY incurred costs for Tropical Storm Isaias of $153 million (including $77 million of operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan, $58 million of capital expenditures and $18 million of operation and maintenance expenses). As of December 31, 2020, O&R incurred costs for Tropical Storm Isaias of $34 million (including $26 million of operation and maintenance expenses charged against a storm reserve pursuant to its New York electric rate plan and $8 million of capital expenditures). 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. In addition, as of December 31, 2020, CECONY and O&R incurred costs of $7.5 million and $2.9 million, respectively, for food and medicine spoilage claims. 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 New York State Department of Public Service (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. The Utilities have not accrued a liability related to this matter and are unable to determine the outcome of this proceeding at this time.

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. The Department of Energy is expected to issue regulations implementing the executive order. In January 2021, the president of the United States suspended the May 2020 executive order for 90 days. The Companies are unable to predict the impact on them of regulations that may be adopted regarding the bulk-power system.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2020 and 2019 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Regulatory assets
Unrecognized pension and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	865	732	791	647
Revenue taxes	356	321	342	308
Pension and other postretirement benefits deferrals	315	71	272	47
Property tax reconciliation	241	219	239	210
Deferred storm costs	195	77	83	—
MTA power reliability deferral	188	248	188	248
System peak reduction and energy efficiency programs	124	131	124	130
Deferred derivative losses	120	83	111	76
COVID - 19 Deferrals	115	—	113	—
Municipal infrastructure support costs	62	75	62	75
Brooklyn Queens demand management program	36	39	36	39
Meadowlands heater odorization project	32	35	32	35
Gate station upgrade project	25	19	25	19
Unamortized loss on reacquired debt	21	28	19	26
Preferred stock redemption	21	22	21	22
Recoverable REV demonstration project costs	20	21	18	19
Non-wire alternative projects	18	14	18	14
Workers’ compensation	—	3	—	3
Other	200	180	186	166
Regulatory assets – noncurrent	6,195	4,859	5,745	4,487
Deferred derivative losses	190	128	177	113
Recoverable energy costs	76	—	67	—
Regulatory assets – current	266	128	244	113
Total Regulatory Assets	$6,461	$4,987	$5,989	$4,600
Regulatory liabilities
Future income tax*	$2,207	$2,426	$2,062	$2,275
Allowance for cost of removal less salvage	1,090	989	932	843
TCJA net benefits	295	471	286	454
Net unbilled revenue deferrals	198	199	198	199
Net proceeds from sale of property	137	173	137	173
Pension and other postretirement benefit deferrals	85	75	46	46
System benefit charge carrying charge	64	48	57	44
Property tax refunds	36	45	35	45
BQDM and REV Demo reconciliations	27	27	25	26
Settlement of gas proceedings	21	10	21	10
Sales and use tax refunds	16	8	16	8
Earnings sharing - electric, gas and steam	15	22	10	15
Unrecognized other postretirement costs	11	9	—	—
Settlement of prudence proceeding	5	8	5	8
Workers’ compensation	3	—	3	—
Energy efficiency portfolio standard unencumbered funds	1	122	—	118
Other	302	195	261	163
Regulatory liabilities – noncurrent	4,513	4,827	4,094	4,427
Refundable energy costs	28	44	4	12
Deferred derivative gains	8	34	7	34
Revenue decoupling mechanism	—	24	—	17
Regulatory liabilities—current	36	102	11	63
Total Regulatory Liabilities	$4,549	$4,929	$4,105	$4,490

* See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.

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

MTA power reliability deferral represents CECONY’s costs in excess of those reflected in its prior electric rate plan to take certain actions relating to the electrical equipment that serves the Metropolitan Transportation Authority (MTA) subway system. The company is recovering this regulatory asset pursuant to its current electric rate plan. See footnote (d) to the CECONY - Electric table under “Rate Plans,” above.

Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Tropical Storm Isaias, Superstorm Sandy and other major storms that were deferred by the Utilities.

Settlement of prudence proceeding represents the remaining amount to be credited to customers pursuant to a Joint Proposal, approved by the NYSPSC in April 2016, with respect to the prudence of certain CECONY expenditures and related matters.

Settlement of gas proceedings represents the amount to be credited to customers pursuant to a settlement agreement approved by the NYSPSC in February 2017 related to CECONY’s practices of qualifying persons to perform plastic fusions on gas facilities and alleged violations of gas safety violations identified by the NYSPSC staff in its investigation of a March 2014 Manhattan explosion and fire (see Note H).

COVID - 19 Deferrals represents both the amount to be collected from customers related to the Emergency Summer Cooling Credits program for CECONY and amounts related to the increase in the allowance for uncollectible accounts resulting from the COVID-19 pandemic and New York on PAUSE and related executive orders, for electric and gas operations for CECONY and electric operations for O&R.

The NYSPSC has authorized CECONY to accrue unbilled electric, gas and steam revenues. CECONY has deferred the net margin on the unbilled revenues for the future benefit of customers by recording a regulatory liability of $198 million and $199 million at December 31, 2020 and 2019, respectively, for the difference between the unbilled revenues and energy cost liabilities.

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.

In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made ($1,696 million and $1,188 million for Con Edison, and $1,509 and $1,054 million for CECONY at December 31, 2020 and 2019, respectively). Regulatory liabilities are treated in a consistent manner. The Other Customer-Provided Capital rate for the years ended December 31, 2020 and 2019 was 2.65 percent and 4.2 percent, respectively. The recognition of the return on regulatory assets is determined by the Utilities’ rate plans or orders issued by state regulators.

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 December 31, 2020 and 2019, 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)	2020	2019	2020	2019
Unrecognized and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	855	727	781	647
Revenue taxes	336	296	323	285
Deferred derivative losses	120	83	111	76
Workers' compensation	—	3	—	3
Other	24	21	24	20
Deferred derivative losses - current	190	128	177	112
Total	4,766	3,799	4,481	3,546

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 represent the 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.

Electricity Purchase Agreements

The Utilities have electricity purchase agreements with non-utility generators and others for generating capacity. The Utilities recover their purchased power costs in accordance with provisions approved by the applicable state public utility regulators. See “Recoverable Energy Costs” in Note A. The Utilities also conducted auctions and have entered into various other electricity purchase agreements. Assuming performance by the parties to the electricity purchase agreements, the Utilities are obligated over the terms of the agreements to make capacity and other fixed payments.

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

(Millions of Dollars)	2021	2022	2023	2024	2025	All Years Thereafter
Con Edison	$141	$106	$68	$53	$54	$487
CECONY	138	106	68	53	54	487

For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the significant terms of the agreements for capacity, energy and other fixed payments in 2020, 2019 and 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Indian Point (a)	$—	$—	$6
Astoria Generating Company (b)	26	116	179
Brooklyn Navy Yard (c)	113	115	124
Cogen Technologies	—	—	9
Total	$139	$231	$318

(a) Contract term ended in 2018.

(b) Capacity purchase agreements with terms ending in 2020 and 2023.

(c) Contract for plant output, which started in 1996 and ends in 2036.

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Leases

12 Months Ended

Dec. 31, 2020

Leases [Abstract]

Leases

Leases

In January 2019, the Companies adopted Accounting Standards Update (ASU) No. 2016-02, “Leases (Topic 842),” including the amendments thereto, using a modified retrospective transition method of adoption that required no prior period adjustments or charges to retained earnings for cumulative impact. The standard supersedes the lease requirements within ASC Topic 840, “Leases.” The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognized lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases.

For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 40 years and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. The Companies account for lease and non-lease components as a single lease component.

Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the twelve months ended December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Operating lease cost	$85	$83	$65	$64
Operating lease cash flows	$79	$75	$61	$60

As of December 31, 2020, assets recorded as finance leases for Con Edison and CECONY were $3 million and $2 million, respectively, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively. As of December 31, 2019, assets recorded as finance leases were $1 million for Con Edison and an immaterial amount for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $5 million and $3 million, respectively.

For the twelve months ended December 31, 2020 and 2019, finance lease costs and cash flows for Con Edison and CECONY were immaterial.

Right-of-use assets obtained in exchange for lease obligations for Con Edison and CECONY were $23 million and $11 million, respectively, for the twelve months ended December 31, 2020 and $39 million and $4 million, respectively, for the twelve months ended December 31, 2019.

Other information related to leases for Con Edison and CECONY at December 31, 2020 and 2019 was as follows:

	Con Edison		CECONY
	2020	2019	2020	2019
Weighted Average Remaining Lease Term:
Operating leases	19.1 years	19.8 years	13.0 years	14.0 years
Finance leases	7.3 years	12.2 years	4.0 years	2.4 years
Weighted Average Discount Rate:
Operating leases	4.3%	4.3%	3.6%	3.6%
Finance leases	1.8%	3.5%	1.3%	4.1%

Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending December 31,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2021	$79	$1	$62	$1
2022	77	1	58	1
2023	74	—	57	—
2024	75	—	57	—
2025	75	—	58	—
All years thereafter	938	1	451	—
Total future minimum lease payments	$1,318	$3	$743	$2
Less: imputed interest	(458)	—	(158)	—
Total	$860	$3	$585	$2
Reported as of December 31, 2020
Operating lease liabilities (current)	$96	$—	$73	$—
Operating lease liabilities (noncurrent)	764	—	512	—
Other current liabilities	—	1	—	1
Other noncurrent liabilities	—	2	—	1
Total	$860	$3	$585	$2

At December 31, 2020, 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 twelve months ended December 31, 2020 and 2019.

Leases

Leases

In January 2019, the Companies adopted Accounting Standards Update (ASU) No. 2016-02, “Leases (Topic 842),” including the amendments thereto, using a modified retrospective transition method of adoption that required no prior period adjustments or charges to retained earnings for cumulative impact. The standard supersedes the lease requirements within ASC Topic 840, “Leases.” The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. The Companies recognized lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases.

For new operating leases, the Companies recognize operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term at commencement date. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 40 years and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees. The Companies account for lease and non-lease components as a single lease component.

Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the twelve months ended December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Operating lease cost	$85	$83	$65	$64
Operating lease cash flows	$79	$75	$61	$60

As of December 31, 2020, assets recorded as finance leases for Con Edison and CECONY were $3 million and $2 million, respectively, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $3 million and $1 million, respectively. As of December 31, 2019, assets recorded as finance leases were $1 million for Con Edison and an immaterial amount for CECONY, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $5 million and $3 million, respectively.

For the twelve months ended December 31, 2020 and 2019, finance lease costs and cash flows for Con Edison and CECONY were immaterial.

Right-of-use assets obtained in exchange for lease obligations for Con Edison and CECONY were $23 million and $11 million, respectively, for the twelve months ended December 31, 2020 and $39 million and $4 million, respectively, for the twelve months ended December 31, 2019.

Other information related to leases for Con Edison and CECONY at December 31, 2020 and 2019 was as follows:

	Con Edison		CECONY
	2020	2019	2020	2019
Weighted Average Remaining Lease Term:
Operating leases	19.1 years	19.8 years	13.0 years	14.0 years
Finance leases	7.3 years	12.2 years	4.0 years	2.4 years
Weighted Average Discount Rate:
Operating leases	4.3%	4.3%	3.6%	3.6%
Finance leases	1.8%	3.5%	1.3%	4.1%

Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending December 31,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2021	$79	$1	$62	$1
2022	77	1	58	1
2023	74	—	57	—
2024	75	—	57	—
2025	75	—	58	—
All years thereafter	938	1	451	—
Total future minimum lease payments	$1,318	$3	$743	$2
Less: imputed interest	(458)	—	(158)	—
Total	$860	$3	$585	$2
Reported as of December 31, 2020
Operating lease liabilities (current)	$96	$—	$73	$—
Operating lease liabilities (noncurrent)	764	—	512	—
Other current liabilities	—	1	—	1
Other noncurrent liabilities	—	2	—	1
Total	$860	$3	$585	$2

At December 31, 2020, 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 twelve months ended December 31, 2020 and 2019.

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Goodwill	12 Months Ended
	Dec. 31, 2020
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The Companies test goodwill for impairment at least annually or whenever there is a triggering event. There is an option to first make a qualitative assessment of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount before applying a quantitative goodwill impairment test. The quantitative goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, an impairment loss shall be recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit.Con Edison has recorded goodwill related to the O&R merger, the acquisition of a gas storage company by CET Gas, and the acquisitions of a residential solar company and battery storage company by the Clean Energy Businesses. In 2020 and 2019, Con Edison completed impairment tests for their goodwill of $406 million related to the O&R merger and determined that it was not impaired. For the impairment test, $245 million and $161 million of goodwill were allocated to CECONY and O&R, respectively. In 2019, the Companies performed the optional qualitative assessment for goodwill related to the O&R merger. In 2020 and 2019, Con Edison completed impairment tests for goodwill of $8 million related to the gas storage company acquired by CET Gas, $14 million related to the residential solar company acquired by the Clean Energy Businesses and $18 million related to the battery storage company acquired by the Clean Energy Businesses, and determined that they were not impaired. Estimates of future cash flows, projected growth rates, and discount rates inherent in the cash flow estimates for Con Edison subsidiaries other than the Utilities may vary significantly from actual results, which could result in a future impairment of goodwill. 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 may not be recoverable at December 31, 2020.

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Income Tax

12 Months Ended

Dec. 31, 2020

Income Tax Disclosure [Abstract]

Income Tax

Income Tax

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 was carried back to tax year 2013, which had a 35 percent federal statutory tax rate. This income tax benefit was primarily recognized at the Clean Energy Businesses.

The components of income tax are as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
State
Current	$7	$(12)	$(10)	$6	$22	$6
Deferred	50	96	107	97	68	82
Federal
Current	(2)	—	3	41	185	(34)
Deferred	42	219	310	73	63	275
Amortization of investment tax credits	(7)	(7)	(9)	(2)	(3)	(3)
Total income tax expense	$90	$296	$401	$215	$335	$326

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

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Deferred tax liabilities:
Property basis differences	$7,985	$7,699	$6,901	$6,640
Regulatory assets:
Unrecognized pension and other postretirement costs	910	712	861	674
Environmental remediation costs	243	205	222	181
Deferred storm costs	31	22	—	—
Other regulatory assets	536	376	508	355
Operating lease right-of-use asset	220	231	165	169
Equity investments	46	104	—	—
Total deferred tax liabilities	$9,971	$9,349	$8,657	$8,019
Deferred tax assets:
Accrued pension and other postretirement costs	$504	$291	$427	$222
Regulatory liabilities:
Future income tax	617	678	579	638
Other regulatory liabilities	656	702	570	622
Superfund and other environmental costs	241	206	219	183
Asset retirement obligations	178	135	143	102
Operating lease liabilities	211	231	165	170
Loss carryforwards	164	108	34	—
Tax credits carryforward	1,022	896	—	—
Valuation allowance	(22)	(31)	—	—
Other	59	47	127	103
Total deferred tax assets	3,630	3,263	2,264	2,040
Net deferred tax liabilities	$6,341	$6,086	$6,393	$5,979
Unamortized investment tax credits	134	141	18	21
Net deferred tax liabilities and unamortized investment tax credits	$6,475	$6,227	$6,411	$6,000

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

	Con Edison						CECONY
(% of Pre-tax income)	2020		2019		2018		2020		2019		2018
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	4		4		4		5		5		5
Taxes attributable to noncontrolling interests	(1)		(1)		—		—		—		—
Cost of removal	2		1		1		1		1		1
Other plant-related items	(1)		(1)		(1)		(1)		(1)		(1)
TCJA deferred tax re-measurement	—		—		2		—		—		—
Amortization of excess deferred federal income taxes	(14)		(4)		(3)		(12)		(4)		(3)
Renewable energy credits	(3)		(2)		(1)		—		—		—
Research and development credits	—		(1)		—		—		(1)		(1)
Other	(1)		—		—		1		—		(1)
Effective tax rate	7	%	17	%	23	%	15	%	21	%	21	%

CECONY and O&R deferred as regulatory liabilities their estimated net benefits under the TCJA for the year ended December 31, 2018. CECONY’s net benefits prior to January 1, 2019 for its electric service and amortization of excess deferred federal income taxes for its electric service continued to be deferred. RECO deferred as a regulatory liability its estimated net benefits under the TCJA for the three months ended March 31, 2018. The net benefits include the revenue requirement impact of the reduction in the corporate federal income tax rate to 21 percent, the elimination for utilities of bonus depreciation and the amortization of excess deferred federal income taxes the utilities collected from customers that will not be paid to the IRS under the TCJA. See “Other Regulatory Matters” in Note B.

At December 31, 2020, Con Edison has a federal NOL of approximately $21 million that can be carried forward indefinitely. Con Edison also has $1,022 million in general business tax credit carryovers (primarily renewable energy tax credits), which if unused will begin to expire in 2032. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance was provided, as it is more likely than not that the deferred tax asset will be realized.

At December 31, 2020, Con Edison has a New York State NOL of approximately $1,351 million, primarily as a result of higher accelerated state tax depreciation. A deferred tax asset has been recognized for these New York State NOL carryforwards that will begin to expire, if unused, in 2039 and no valuation allowance was provided; as it is more likely than not that the deferred tax asset will be realized. In addition, Con Edison reversed $9 million of the valuation allowance against the New York City NOL deferred tax asset that will be realized over the next 10 years. Con Edison also has a $18 million valuation allowance for other state NOL carryforwards; as it is not more likely than not that the deferred tax asset will be realized.

The Protecting Americans from Tax Hikes Act of 2015 extended bonus depreciation applying a 50 percent rate for property acquired and placed in service for years 2015 through 2017 with reduced rates of 40 percent and 30 percent for years 2018 and 2019, respectively. The TCJA does not allow bonus depreciation after December 31, 2017 (excluding certain transition rules) for Companies that qualify as a utility company for the consolidated group under the de minimis exception to Treasury regulations.

In December 2019, the Federal government issued final regulations providing guidance on provisions in the TCJA allowing for full expensing of qualified plant additions. These provisions, which Con Edison adopted under the proposed regulations of August 2018, allowed the Utilities a full expense tax deduction for plant additions in the fourth quarter of 2017, and the Utilities continue additional first year depreciation transition rules for plant additions placed in service in tax years beginning in 2018, under long-term construction contracts entered into before September 28, 2017. The impact on the Utilities of these regulations is discussed above.

In November 2018, the Federal government issued, and Con Edison adopted, proposed regulations providing guidance on the tax deductibility of interest expense under the TCJA. The TCJA generally provides for the continued deductibility of interest expense by regulated public utilities and may limit the deduction for interest expense by most non-utility businesses to 30 percent of adjusted taxable income (which resembles earnings before interest, taxes, depreciation and amortization).The regulations provide an annual safe harbor test that if at least 90 percent of consolidated plant assets consist of utility property, the entire consolidated group will be treated as a regulated public utility, and all of the consolidated group’s interest expense will be currently tax deductible. For 2018, Con Edison met the 90 percent safe harbor test and its deduction for interest expense was not limited. For 2019, Con Edison did not meet the 90 percent safe harbor test, however, its deduction for interest expense was not limited as a percentage of adjusted taxable income. In 2020, the federal government issued final regulations under the TCJA. Under the CARES Act, the limit of the deductible interest expense as a percentage of adjusted taxable income increased from 30 percent to 50 percent and accordingly, all of Con Edison’s interest expense in 2020 will be tax deductible. Qualifying consolidated groups would not be entitled to the full expensing provisions in the TCJA noted above. The safe harbor rules do not apply to partnerships in which Con Edison and its subsidiaries are a partner.

Uncertain Tax Positions

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

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

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Balance at January 1,	$13	$6	$12	$2	$4	$5
Additions based on tax positions related to the current year	—	1	2	—	1	2
Additions based on tax positions of prior years	1	10	1	1	—	1
Reductions for tax positions of prior years	—	(2)	(2)	—	(1)	(1)
Reductions from expiration of statute of limitations	—	—	(4)	—	—	—
Settlements	—	(2)	(3)	—	(2)	(3)
Balance at December 31,	$14	$13	$6	$3	$2	$4

At December 31, 2020, the estimated liability for uncertain tax positions for Con Edison was $14 million ($3 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 $14 million ($13 million, net of federal taxes) with $3 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 year ended December 31, 2020, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At December 31, 2020 and 2019, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

Con Edison's federal tax return for 2019 remains under examination. State and local income tax returns remain open for examination in New York State for tax years 2010 through 2019, in New Jersey for tax years 2016 through 2019 and in New York City for tax years 2015 and 2019.

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Revenue Recognition

12 Months Ended

Dec. 31, 2020

Revenue from Contract with Customer [Abstract]

Revenue Recognition

Revenue Recognition

The following table presents, for the years ended December 31, 2020 and 2019, revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source.

	2020				2019				2018
(Millions of Dollars)	Revenues from contracts with customers		Other revenues (a)	Total operating revenues	Revenues from contracts with customers		Other revenues (a)	Total operating revenues	Revenues from contracts with customers		Other revenues (a)	Total operating revenues
CECONY
Electric	$8,026		$77	$8,103	$7,913		$149	$8,062	$7,920		$51	$7,971
Gas	1,998		38	2,036	2,097		35	2,132	2,052		26	2,078
Steam	494		14	508	610		17	627	625		6	631
Total CECONY	$10,518		$129	$10,647	$10,620		$201	$10,821	$10,597		$83	$10,680
O&R
Electric	619		10	629	627		7	634	647		(5)	642
Gas	224		9	233	247		12	259	256		(7)	249
Total O&R	$843		$19	$862	$874		$19	$893	$903		$(12)	$891
Clean Energy Businesses
Renewables	609	(b)	—	609	575	(b)	—	575	329	(b)	—	329
Energy services	52		—	52	71		—	71	95		—	95
Other	—		75	75	—		211	211	—		339	339
Total Clean Energy Businesses	$661		$75	$736	$646		$211	$857	$424		$339	$763
Con Edison Transmission	4		—	4	4		—	4	4		—	4
Other (c)	—		(3)	(3)	—		(1)	(1)	—		(1)	(1)
Total Con Edison	$12,026		$220	$12,246	$12,144		$430	$12,574	$11,928		$409	$12,337

(a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans. For the Clean Energy Businesses, this includes revenue from wholesale services.

(b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $8 million, $14 million and $103 million for the years ended December 31, 2020, 2019 and 2018, respectively, of revenue related to engineering, procurement and construction services.

(c) Parent company and consolidation adjustments.

Revenues are recorded as energy is delivered, generated or services are provided and billed to customers, except for services under percentage-of-completion contracts. Amounts billed are recorded in accounts receivable - customers, with payment generally due the following month. Con Edison’s and the Utilities’ accounts receivable - customers balance also reflects the Utilities’ purchase of receivables from energy service companies to support retail choice programs. Accrued revenues not yet billed to customers are recorded as accrued unbilled revenues.

The Utilities have the obligation to deliver electricity, gas and steam energy to their customers. As the energy is immediately available for use upon delivery to the customer, the energy and its delivery are identifiable as a single performance obligation. The Utilities recognize revenues as this performance obligation is satisfied over time as the Utilities deliver, and the customers simultaneously receive and consume, the energy. The amount of revenues recognized reflects the consideration the Utilities expect to receive in exchange for delivering the energy. Under their tariffs, the transaction price for full-service customers includes the Utilities’ energy cost and for all customers includes delivery charges determined based on customer class and in accordance with established tariffs and guidelines of the NYSPSC or the NJBPU, as applicable. Accordingly, there is no unsatisfied performance obligation associated with these customers. The transaction price is applied to the Utilities’ revenue generating activities through the customer billing process. Because energy is delivered over time, the Utilities use output methods that recognize revenue based on direct measurement of the value transferred, such as units delivered, which provides an accurate measure of value for the energy delivered. The Utilities accrue revenues at the end of each month for estimated energy delivered but not yet billed to customers. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers.

The Clean Energy Businesses recognize revenue for the sale of energy from renewable electric production projects as energy is generated and billed to counterparties; accrue revenues at the end of each month for energy generated but not yet billed to counterparties; and recognize revenue as energy is delivered and services are provided for managing energy supply assets leased from others and managing the dispatch, fuel requirements and risk management activities for generating plants and merchant transmission in the northeastern United States. The Clean Energy Businesses also recognize revenue for providing energy-efficiency services to government and commercial customers, and recognize revenue for engineering, procurement and construction services, under the percentage-of-completion method of revenue recognition.

Sales and profits on each percentage-of-completion contract are recorded each month based on the ratio of actual cumulative costs incurred to the total estimated costs at completion of the contract, multiplied by the total estimated contract revenue, less cumulative revenues recognized in prior periods (the ‘‘cost-to-cost’’ method). The impact of revisions of contract estimates, which may result from contract modifications, performance or other reasons, are recognized on a cumulative catch-up basis in the period in which the revisions are made.

	2020			2019			2018
(Millions of Dollars)	Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)
Beginning balance as of January 1,	$29	$17		$29	$20		$58	$87
Additions (c)	88	31		86	1		144	38
Subtractions (c)	106	7	(d)	86	4	(d)	173	105	(d)
Ending balance as of December 31,	$11	$41		$29	$17		$29	$20

(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, $7 million, $4 million and $50 million were included in the balances as of January 1, 2020, 2019, and 2018, respectively.

As of December 31, 2020, the aggregate amount of the remaining fixed performance obligations of the Clean Energy Businesses under contracts with customers for energy services is $216 million, of which $181 million will be recognized within the next two years, and the remaining $35 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.

The estimated amount of these foregone revenues for the year ended December 31, 2020 was $64 million and $61 million for Con Edison and CECONY, 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. See "COVID-19 Regulatory Matters" in Note B.

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Stock-Based Compensation

12 Months Ended

Dec. 31, 2020

Share-based Payment Arrangement [Abstract]

Stock-Based Compensation

Stock-Based Compensation

The Companies may compensate employees and directors with, among other things, stock options, stock units, restricted stock units and contributions to the stock purchase plan. The Long Term Incentive Plan, which was approved by Con Edison’s shareholders in 2003 (2003 LTIP), and the Long Term Incentive Plan, which was approved by Con Edison’s shareholders in 2013 (2013 LTIP), are collectively referred to herein as the LTIP. The LTIP provides for, among other things, awards to employees of restricted stock units and stock options and, to Con Edison’s non-employee directors, stock units. Existing awards under the 2003 LTIP continue in effect, however no new awards may be issued under the 2003 LTIP. The 2013 LTIP provides for awards for up to five million shares of common stock.

Shares of Con Edison common stock used to satisfy the Companies’ obligations with respect to stock-based compensation may be new shares (authorized, but unissued) or treasury shares (existing treasury shares or shares purchased in the open market). The shares used during the year ended December 31, 2020 were new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2021.

The Companies recognized stock-based compensation expense using a fair value measurement method. The following table summarizes stock-based compensation expense recognized by the Companies in the years ended December 31, 2020, 2019 and 2018:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Performance-based restricted stock	$7	$36	$3	$6	$30	$3
Time-based restricted stock	1	2	2	1	2	1
Non-employee director deferred stock compensation	2	2	3	2	2	3
Stock purchase plan	7	7	6	7	6	6
Total	$17	$47	$14	$16	$40	$13
Income tax benefit	$5	$13	$4	$4	$11	$4

Restricted Stock and Stock Units

Restricted stock and stock unit awards under the LTIP have been made as follows: (i) awards that provide for adjustment of the number of units (performance-restricted stock units or Performance RSUs) to certain officers and employees; (ii) time-based awards to certain employees; and (iii) awards to non-employee directors. Restricted stock and stock units awarded represent the right to receive, upon vesting, shares of Con Edison common stock, or, except for units awarded under the directors’ plan, the cash value of shares or a combination thereof.

The number of units in each annual Performance RSU award is subject to adjustment as follows: (i) 50 percent of the units awarded will be multiplied by a factor that may range from 0 to 200 percent, based on Con Edison’s total shareholder return relative to a specified peer group during a specified performance period (the TSR portion); and (ii) 50 percent of the units awarded will be multiplied by factors that may range from 0 to 200 percent, based on determinations made in connection with the Companies’ annual incentive plans or, for certain executive officers, actual performance as compared to certain performance measures during a specified performance period (the non-TSR portion). Performance RSU awards generally vest upon completion of the performance period.

Performance against the established targets is recomputed each reporting period as of the earlier of the reporting date and the vesting date. The TSR portion applies a Monte Carlo simulation model, and the non-TSR portion is the product of the market price at the end of the period and the average non-TSR determination over the vesting period. Performance RSUs are “liability awards” because each Performance RSU represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, changes in the fair value of the Performance RSUs are reflected in net income. The assumptions used to calculate the fair value of the awards were as follows:

	2020	2019	2018
Risk-free interest rate (a)	0.10% - 0.13%	1.58% - 1.59%	2.48% -2.63%
Expected term (b)	3 years	3 years	3 years
Expected share price volatility (c)	30.16% - 40.95%	12.89% - 15.51%	14.76% - 17.71%

(a)The risk-free rate is based on the U.S. Treasury zero-coupon yield curve.

(b)The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur.

(c)Based on historical experience.

A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2020 is as follows:

	Con Edison			CECONY
		Weighted Average Grant Date Fair Value (a)			Weighted Average Grant Date Fair Value (a)
	Units	TSR Portion (b)	Non-TSR Portion (c)	Units	TSR Portion (b)	Non-TSR Portion (c)
Non-vested at December 31, 2019	991,238	$68.15	$77.14	742,204	$68.06	$77.32
Granted	329,600	79.98	90.48	249,761	79.70	89.65
Vested	(326,496)	73.07	74.57	(245,269)	72.70	74.76
Forfeited	(92,818)	73.80	87.98	(60,225)	73.61	87.73
Non-vested at December 31, 2020	901,524	$70.11	$81.83	686,471	$70.15	$81.80

(a)The TSR and non-TSR Portions each account for 50 percent of the awards’ value.

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

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

The total expense to be recognized by Con Edison in future periods for unvested Performance RSUs outstanding at December 31, 2020 is $21 million, including $17 million for CECONY, and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY. Con Edison and CECONY paid cash of $21 million and $18 million in 2020, $24 million and $22 million in 2019, and $29 million and $28 million in 2018, respectively, to settle vested Performance RSUs.

In accordance with the accounting rules for stock compensation, for time-based awards, the Companies are accruing a liability and recognizing compensation expense based on the market value of a common share throughout the vesting period. The vesting period for awards is three years and is based on the employee’s continuous service to Con Edison. Prior to vesting, the awards are subject to forfeiture in whole or in part under certain circumstances. The awards are “liability awards” because each restricted stock unit represents the right to receive, upon vesting, one share of Con Edison common stock, the cash value of a share or a combination thereof. As such, prior to vesting, changes in the fair value of the units are reflected in net income.

A summary of changes in the status of time-based awards during the year ended December 31, 2020 is as follows:

	Con Edison		CECONY
	Units	Weighted Average Grant Date Fair Value	Units	Weighted Average Grant Date Fair Value
Non-vested at December 31, 2019	67,250	$80.36	63,100	$80.36
Granted	22,450	78.00	20,900	78.00
Vested	(20,750)	77.66	(19,650)	77.66
Forfeited	(1,512)	80.30	(1,512)	80.30
Non-vested at December 31, 2020	67,438	$80.40	62,838	$80.42

The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2020 for Con Edison and CECONY was $2 million and is expected to be recognized over a weighted average period of one year. Con Edison and CECONY paid cash of $1 million in 2020, 2019 and 2018, to settle vested time-based awards.

Under the LTIP, each non-employee director receives stock units, which are deferred until the director’s separation from service or another date specified by the director. Each director may also elect to defer all or a portion of their cash compensation into additional stock units, which are deferred until the director’s termination of service or another date specified by the director. Non-employee directors’ stock units issued under the LTIP are considered “equity awards,” because they may only be settled in shares. Directors immediately vest in units issued to them.

The fair value of the units is determined using the closing price of Con Edison’s common stock on the business day immediately preceding the date of issue. In the year ended December 31, 2020, approximately 33,200 units were issued at a weighted average grant date price of $74.32.

Stock Purchase Plan

The Stock Purchase Plan, which was approved by shareholders in 2004 and 2014, provides for the Companies to contribute up to $1 for each $9 invested by their directors, officers or employees to purchase Con Edison common stock under the plan. Eligible participants may invest up to $25,000 during any calendar year (subject to an additional limitation for officers and employees of not more than 20 percent of their pay). Dividends paid on shares held under the plan are reinvested in additional shares unless otherwise directed by the participant.

Participants in the plan immediately vest in shares purchased by them under the plan. Prior to September 1, 2020, the fair value of the shares of Con Edison common stock purchased under the plan was calculated using the average of the high and low composite sale prices at which shares were traded at the New York Stock Exchange on the trading day immediately preceding such purchase dates. During 2020, the plan was amended and as a result of the amendment, the fair value of the shares of Con Edison common stock purchased after September 1, 2020 under the plan was calculated using the closing price at which shares were traded on the New York Stock Exchange on the last business day of the month for all shares purchased during the month. During 2020, 2019 and 2018, 836,984, 747,899 and 786,385 shares were purchased under the Stock Purchase Plan at a weighted average price of $79.82, $85.45 and $78.27 per share, respectively.

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Financial Information by Business Segment

12 Months Ended

Dec. 31, 2020

Segment Reporting [Abstract]

Financial Information by Business Segment

Financial Information by Business Segment

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

Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities.

All revenues of these business segments are from customers located in the United States of America. Also, all assets of the business segments are located in the United States of America. The accounting policies of the segments are the same as those described in Note A.

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

The financial data for the business segments are as follows:

As of and for the Year Ended December 31, 2020 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$8,103	$18	$1,214	$1,731	$(134)	$535	$130	$35,673	$2,080
Gas	2,036	7	294	574	(25)	164	102	12,678	1,044
Steam	508	74	90	5	(12)	40	(14)	2,616	122
Consolidation adjustments	—	(99)	—	—	—	—	—	—	—
Total CECONY	$10,647	$—	$1,598	$2,310	($171)	$739	$218	$50,967	$3,246
O&R
Electric	$629	$—	$65	$99	$(10)	$26	$13	$2,097	$159
Gas	233	—	25	48	(4)	15	8	1,150	61
Other	—	—	—	—	—	—	—	—	—
Total O&R	$862	$—	$90	$147	$(14)	$41	$21	$3,247	$220
Clean Energy Businesses	$736	$—	$231	$215	$4	$196	$(43)	$6,848	$616
Con Edison Transmission	4	—	1	(8)	(215)	18	—	1,348	3
Other (b)	(3)	—	—	(10)	(5)	25	(3)	485	—
Total Con Edison	$12,246	$—	$1,920	$2,654	$(401)	$1,019	$193	$62,895	$4,085

As of and for the Year Ended December 31, 2019 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$8,062	$17	$1,053	$1,758	$(28)	$539	$239	$32,988	$1,851
Gas	2,132	7	231	528	(4)	147	99	11,090	1,078
Steam	627	70	89	62	(3)	42	4	2,479	91
Consolidation adjustments	—	(94)	—	—	—	—	—	—	—
Total CECONY	$10,821	$—	$1,373	$2,348	$(35)	$728	$342	$46,557	$3,020
O&R
Electric	$634	$—	$60	$98	$(7)	$27	$15	$2,130	$142
Gas	259	—	24	41	(4)	14	6	876	61
Other	—	—	—	—	—	—	—	—	—
Total O&R	$893	$—	$84	$139	$(11)	$41	$21	$3,006	$203
Clean Energy Businesses	$857	$—	$226	$202	$5	$186	$(58)	$6,528	$248
Con Edison Transmission	4	—	1	(6)	104	25	1	1,618	205
Other (b)	(1)	—	—	(7)	(12)	11	(6)	370	—
Total Con Edison	$12,574	$—	$1,684	$2,676	$51	$991	$300	$58,079	$3,676

As of and for the Year Ended December 31, 2018 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$7,971	$16	$984	$1,799	$(110)	$519	$233	$31,012	$1,861
Gas	2,078	7	205	478	(23)	131	87	9,710	1,050
Steam	631	75	87	77	(10)	39	8	2,386	94
Consolidation adjustments	—	(98)	—	—	—	—	—	—	—
Total CECONY	$10,680	$—	$1,276	$2,354	$(143)	$689	$328	$43,108	$3,005
O&R
Electric	$642	$—	$56	$93	$(14)	$25	$14	$2,036	$138
Gas	249	—	21	39	(5)	14	7	856	67
Other	—	—	—	—	—	—	—	—	—
Total O&R	$891	$—	$77	$132	$(19)	$39	$21	$2,892	$205
Clean Energy Businesses	$763	$—	$85	$194	$33	$63	$19	$5,821	$1,791
Con Edison Transmission	4	—	1	(7)	91	20	(1)	1,425	248
Other (b)	(1)	—	(1)	(9)	(24)	8	39	674	—
Total Con Edison	$12,337	$—	$1,438	$2,664	$(62)	$819	$406	$53,920	$5,249

(a)For Con Edison, the income tax expense/(benefit) on non-operating income was $(103) million, $(4) million and $(5) million in 2020, 2019 and 2018, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(3) million, $(7) million and $(2) million in 2020, 2019 and 2018, respectively.

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

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Derivative Instruments and Hedging Activities

12 Months Ended

Dec. 31, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. 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 Q), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules.

In August 2017, the FASB issued amendments to the guidance for derivatives and hedging through ASU 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities.” The amendments in this update provide greater clarification on hedge accounting for risk components, presentation and disclosure of hedging instruments, and overall targeted improvements to simplify hedge accounting. The amendments were effective for reporting periods beginning after December 15, 2018. The application of the guidance did not have a material impact on the Companies’ financial position, results of operations and liquidity because the Companies do not elect hedge accounting for their derivative instruments and hedging activities.

The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2020 and 2019 were:

(Millions of Dollars)	2020				2019
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	$44	$14	$58	(b)	$60	$(3)	$57	(b)
Noncurrent	22	35	57		19	(13)	6	(d)
Total fair value of derivative assets	$66	$49	$115		$79	$(16)	$63
Fair value of derivative liabilities
Current	$(225)	$(13)	$(238)	(c)	$(140)	$17	$(123)	(d)
Noncurrent	(207)	(33)	(240)	(c)	(122)	16	(106)	(d)
Total fair value of derivative liabilities	$(432)	$(46)	$(478)		$(262)	$33	$(229)
Net fair value derivative assets/(liabilities)	$(366)	$3	$(363)		$(183)	$17	$(166)
CECONY
Fair value of derivative assets
Current	$20	$(12)	$8	(b)	$39	$(6)	$33	(b)
Noncurrent	16	(8)	8		17	(12)	5
Total fair value of derivative assets	$36	$(20)	$16		$56	$(18)	$38
Fair value of derivative liabilities
Current	$(174)	$11	$(163)		$(100)	$19	$(81)
Noncurrent	(114)	9	(105)		(80)	16	(64)
Total fair value of derivative liabilities	$(288)	$20	$(268)		$(180)	$35	$(145)
Net fair value derivative assets/(liabilities)	$(252)	$—	$(252)		$(124)	$17	$(107)

 

(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 December 31, 2020 and 2019, margin deposits for Con Edison ($3 million and $9 million, respectively) and CECONY ($3 million and $8 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

(c)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 range from 2024-2041.

(d)Includes amounts for interest rate swaps of $1 million in current assets, $(7) million in current liabilities and $(34) million in noncurrent liabilities. At December 31, 2019, the Clean Energy Businesses had interest rate swaps with notional amounts of $919 million. The expiration dates of the swaps range 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. See "Recoverable Energy Costs" in Note A. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements.

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 years ended December 31, 2020 and 2019:

		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2020	2019	2020	2019
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(26)	$4	$(27)	$5
Noncurrent	Deferred derivative gains	—	(3)	—	(1)
Total deferred gains/(losses)		$(26)	$1	$(27)	$4
Current	Deferred derivative losses	$(63)	$(91)	$(64)	$(83)
Current	Recoverable energy costs	(201)	(142)	(177)	(124)
Noncurrent	Deferred derivative losses	(37)	(67)	(36)	(65)
Total deferred gains/(losses)		$(301)	$(300)	$(277)	$(272)
Net deferred gains/(losses)		$(327)	$(299)	$(304)	$(268)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Gas purchased for resale	$(2)	$(2)	$—	$—
	Non-utility revenue	7	25	—	—
	Other operations and maintenance expense	(3)	1	(3)	1
	Other interest expense	(65)	(36)	—	—
Total pre-tax gain/(loss) recognized in income		$(63)	$(12)	$(3)	$1

 

The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2020:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	28,102,230	47,258	286,819,910	7,728,000
CECONY	26,193,800	35,400	267,380,000	7,728,000

 

(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 December 31, 2020, Con Edison and CECONY had $217 million and $16 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 $103 million with independent system operators, $47 million with investment-grade counterparties, $40 million with non-investment grade/non-rated counterparties, and $27 million with commodity exchange brokers. CECONY’s net credit exposure consisted of $16 million with commodity exchange brokers.

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 December 31, 2020:

(Millions of Dollars)	Con Edison (a)	CECONY (a)
Aggregate fair value – net liabilities	$293	$277
Collateral posted	212	200
Additional collateral (b) (downgrade one level from current ratings)	5	—
Additional collateral (b)(c) (downgrade to below investment grade from current ratings)	101	85

 

(a)Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $25 million at December 31, 2020. 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 December 31, 2020, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $51 million.

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Fair Value Measurements

12 Months Ended

Dec. 31, 2020

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.

For information on the measurement of Con Edison's investment in MVP, which was measured at fair value on a non-recurring basis, see Note A. Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2020 and 2019 are summarized below.

	2020					2019
(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)	$19	$42	$4	$53	$118	$4	$61	$2	$4	$71
Interest rate swaps (a)(b)(c)(f)	—	—	—	—	—	—	1	—	—	1
Other (a)(b)(d)	431	126	—	—	557	353	125	—	—	478
Total assets	$450	$168	$4	$53	$675	$357	$187	$2	$4	$550
Derivative liabilities:
Commodity (a)(b)(c)	$7	$296	$23	$46	$372	$18	$174	$18	$(22)	$188
Interest rate swaps (a)(b)(c)(f)	—	106	—	—	106	—	41	—	—	41
Total liabilities	$7	$402	$23	$46	$478	$18	$215	$18	$(22)	$229
CECONY
Derivative assets:
Commodity (a)(b)(c)	$15	$20	$—	$(16)	$19	$3	$42	$1	$—	$46
Other (a)(b)(d)	411	120	—	—	531	333	119	—	—	452
Total assets	$426	$140	$—	$(16)	$550	$336	$161	$1	$—	$498
Derivative liabilities:
Commodity (a)(b)(c)	$3	$274	$10	$(19)	$268	$15	$147	$7	$(24)	$145

 

(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 $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. Con Edison and CECONY had $24 million and $22 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2019 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of December 31, 2017 to less than three years as of December 31, 2019.

(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 December 31, 2020 and 2019, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.

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

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

(f)See Note P.

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 December 31, 2020
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison — Commodity
Electricity	(20)	Discounted Cash Flow	Forward capacity prices (a)	$0.06-$6.26 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(2.65)-$7.69 per MWh
Total Con Edison — Commodity	$(19)
CECONY — Commodity
Electricity	$(11)	Discounted Cash Flow	Forward capacity prices (a)	$0.08-$6.26 per kW-month
Transmission Congestion Contracts	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.23-$1.13 per MWh
Total CECONY — Commodity	$(10)

 

(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 for the years ended December 31, 2020 and 2019 and classified as Level 3 in the fair value hierarchy:

 

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Beginning balance as of January 1,	$(16)	$(13)	$(6)	$(2)
Included in earnings	(10)	(5)	(5)	—
Included in regulatory assets and liabilities	(7)	18	(4)	17
Settlements	15	8	6	1
Transfer out of level 3	(1)	(24)	(1)	(22)
Ending balance as of December 31,	$(19)	$(16)	$(10)	$(6)

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. See Note A. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations.

For the Clean Energy Businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ($3 million gain and $2 million gain) on the consolidated income statement for the years ended December 31, 2020 and 2019, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at December 31, 2020 and 2019 is included in non-utility revenues ($2 million gain) on the consolidated income statement for the years ended December 31, 2020 and 2019.

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Variable Interest Entities

12 Months Ended

Dec. 31, 2020

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. In April 2017, CECONY's long-term electricity purchase agreement with Cogen Technologies Linden Venture, LP (Linden Cogeneration), another potential VIE, expired. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY's maximum exposure to loss with respect to the potential VIEs.

Clean Energy Businesses

In September 2019, the Clean Energy Businesses, which previously owned an 80 percent membership interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), acquired the remaining 20 percent interest. As a result of the acquisition, Texas Solar 4 is a consolidated entity. Prior to the acquisition, Con Edison had a variable interest in Texas Solar 4, as to which Con Edison was the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 was held by the Clean Energy Businesses. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project. Electricity generated by the project is sold pursuant to a long-term power purchase agreement. Con Edison's earnings from Texas Solar 4 for the years ended December 31, 2019 and 2018 were immaterial.

In December 2018, the Clean Energy Businesses completed its acquisition of Sempra Solar Holdings, LLC. See Note V. 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 year ended December 31, 2020, the hypothetical liquidation at book value (HLBV) method of accounting for the Tax Equity Projects resulted in $44 million of income ($32 million, after tax) for the tax equity investor and a $6 million loss ($4 million, after tax) for Con Edison. For the year ended December 31, 2019, the HLBV method of accounting for the Tax Equity Projects resulted in $98 million of income ($74 million, after tax) for the tax equity investor and a $64 million loss ($48 million, after tax) for Con Edison, and earnings under the HLBV method for the year ended December 31, 2018 were immaterial.

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 December 31, 2020 and 2019, 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)
(Millions of Dollars)	2020	2019	2020	2019
Non-utility property, less accumulated depreciation (f)(g)	284	293	446	461
Other assets	39	40	176	128
Total assets (a)	$323	$333	$622	$589
Other liabilities	13	17	71	18
Total liabilities (b)	$13	$17	$71	$18

(a)The assets of the Tax Equity Projects 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 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 $82 million and $62 million at December 31, 2020 and 2019, 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 $134 million and $126 million at December 31, 2020 and 2019, respectively.

(f)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.

(g)Non-utility property is reduced by accumulated depreciation of $9 million for Great Valley Solar, $15 million for Copper Mountain - Mesquite Solar at December 31, 2019.

The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2020:

Project Name	Generating Capacity (a) (MW AC)	Power Purchase Agreement Term in Years	Year of Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (b)
Great Valley Solar (c)	200	15-20	2018	California	$228
Copper Mountain - Mesquite Solar (c)	344	20-25	2018	Nevada and Arizona	417

 

(a)Represents ownership interest in the project.

(b)Maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

(c)For the projects comprising Great Valley Solar and Copper Mountain Mesquite Solar, refer to (d) and (e) in the table above.

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Asset Retirement Obligations

12 Months Ended

Dec. 31, 2020

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

The Companies recognize a liability at fair value for legal obligations associated with the retirement of long-lived assets in the period in which they are incurred, or when sufficient information becomes available to reasonably estimate the fair value of such legal obligations. When the liability is initially recorded, asset retirement costs are capitalized by increasing the carrying amount of the related asset. The liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. The fair value of the asset retirement obligation liability is measured using expected future cash flows discounted at credit-adjusted risk-free rates, historical information, and where available, quoted prices from outside contractors. The Companies evaluate these assumptions underlying the asset retirement obligation liability on an annual basis or as frequently as needed.

The Companies recorded asset retirement obligations associated with the removal of asbestos and asbestos-containing material in their buildings (other than the structures enclosing generating stations and substations), electric equipment and steam and gas distribution systems. The Companies also recorded asset retirement obligations relating to gas and oil pipelines abandoned in place and municipal infrastructure support.

The Companies did not record an asset retirement obligation for the removal of asbestos associated with the structures enclosing generating stations and substations. For these building structures, the Companies were unable

to reasonably estimate their asset retirement obligations because the Companies were unable to estimate the undiscounted retirement costs or the retirement dates and settlement dates. The amount of the undiscounted retirement costs could vary considerably depending on the disposition method for the building structures, and the method has not been determined. The Companies anticipate continuing to use these building structures in their businesses for an indefinite period, and so the retirement dates and settlement dates are not determinable.

Con Edison recorded asset retirement obligations for the removal of the Clean Energy Businesses’ solar and wind equipment related to projects located on property that is not owned by them and the term of the arrangement is finite including any renewal options. Con Edison did not record asset retirement obligations for the Clean Energy Businesses’ projects that are located on property that is owned by them because they expect that the equipment will continue to generate electricity at these facilities long past the manufacturer’s warranty at minimal operating expense. Therefore, Con Edison was unable to reasonably estimate the retirement date of this equipment.

The Utilities include in depreciation rates the estimated removal costs, less salvage, for utility plant assets. The amounts related to removal costs that are associated with asset retirement obligations are classified as an asset retirement liability. Pursuant to accounting rules for regulated operations, future removal costs that do not represent legal asset retirement obligations are recorded as regulatory liabilities. Accretion and depreciation expenses related to removal costs that represent legal asset retirement obligations are applied against the Companies’ regulatory liabilities. Asset retirement costs that are recoverable from customers are recorded as regulatory liabilities to reflect the timing difference between costs recovered through the rate-making process and recognition of costs.

At December 31, 2020, the liabilities for asset retirement obligations of Con Edison and CECONY were $576 million and $508 million, respectively. At December 31, 2019, the liabilities for asset retirement obligations of Con Edison and CECONY were $425 million and $362 million, respectively. The change in liabilities at December 31, 2020 was due to changes in estimated cash flows of $191 million and $186 million for Con Edison and CECONY, respectively, and accretion expense of $16 million and $13 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $56 million and $53 million for Con Edison and CECONY, respectively. The change in liabilities at December 31, 2019 was due to changes in estimated cash flows of $(1) million and $96 million for Con Edison and CECONY, respectively, and accretion expense of $14 million and $12 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $38 million for both Con Edison and CECONY. Con Edison and CECONY also recorded reductions of $49 million and $44 million during the years ended December 31, 2020 and 2019, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.

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Related Party Transactions

12 Months Ended

Dec. 31, 2020

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

The NYSPSC generally requires that the Utilities and Con Edison’s other subsidiaries be operated as separate entities. The Utilities and the other subsidiaries are required to have separate operating employees and operating officers of the Utilities may not be operating officers of the other subsidiaries. The Utilities may provide administrative and other services to, and receive such services from, Con Edison and its other subsidiaries only pursuant to cost allocation procedures approved by the NYSPSC. Transfers of assets between the Utilities and Con Edison or its other subsidiaries may be made only as approved by the NYSPSC. The debt of the Utilities is to be raised directly by the Utilities and not derived from Con Edison. Without the prior permission of the NYSPSC, the Utilities may not make loans to, guarantee the obligations of, or pledge assets as security for the indebtedness of Con Edison or its other subsidiaries. The NYSPSC limits the dividends that the Utilities may pay Con Edison. See “Dividends” in Note C. As a result, substantially all of the net assets of CECONY and O&R ($14,849 million and $807 million, respectively), at December 31, 2020, are considered restricted net assets. The NYSPSC may impose additional measures to separate, or “ring fence,” the Utilities from Con Edison and its other subsidiaries. See “Rate Plans” in Note B.

The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2020, 2019 and 2018 were as follows:

	CECONY
(Millions of Dollars)	2020	2019	2018
Cost of services provided	$128	$121	$115
Cost of services received	66	64	73

In addition, CECONY and O&R have joint gas supply arrangements in connection with which CECONY sold to O&R $59 million, $71 million and $83 million of natural gas for the years ended December 31, 2020, 2019 and 2018, respectively. These amounts are net of the effect of related hedging transactions.

The Utilities perform work and incur expenses on behalf of NY Transco, a company in which CET Electric has a 45.7 percent equity interest. The Utilities bill NY Transco for such work and expenses in accordance with established policies. For the years ended December 31, 2020 and 2019, the amounts billed by the Utilities to NY Transco were immaterial. In May 2016, CECONY transferred certain electric transmission projects to NY Transco.

CECONY has storage and wheeling service contracts with Stagecoach Gas Services LLC, (Stagecoach), a joint venture formed by a subsidiary of CET Gas and a subsidiary of Crestwood Equity Partners LP (Crestwood). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. CECONY incurred costs for storage and wheeling services from Stagecoach of $34 million, $33 million and $28 million for the years ended December 31, 2020, 2019 and 2018, respectively.

CECONY has a 20-year transportation contract with Mountain Valley Pipeline, LLC (MVP) for 250,000 dekatherms per day of capacity. CET Gas owns an 11.3 percent equity interest in MVP (that is expected to be reduced to 8.8 percent). See "Investments" in Note A. In October 2017, the Environmental Defense Fund and the Natural Resource Defense Council requested the NYSPSC to prohibit CECONY from recovering costs under its MVP contract unless CECONY can demonstrate that the contract is in the public interest. CECONY advised the NYSPSC that it would respond to the request if the NYSPSC opened a proceeding to consider this request. For the years ended December 31, 2020 and 2019, CECONY incurred no costs under the contract.

FERC has authorized CECONY to lend funds to O&R for a period of not more than 12 months, in an amount not to exceed $250 million, at prevailing market rates. At December 31, 2020 and 2019 there were no outstanding loans to O&R.

The Clean Energy Businesses had financial electric capacity contracts with CECONY and O&R during 2020 and 2019. For the years ended December 31, 2020 and 2019, the Clean Energy Businesses realized an immaterial loss and a $1 million loss, respectively, under these contracts.

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New Financial Accounting Standards

12 Months Ended

Dec. 31, 2020

Accounting Changes and Error Corrections [Abstract]

New Financial Accounting Standards

New Financial Accounting Standards

In December 2019, the FASB issued amendments to the guidance for income taxes through ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” The amendments in this update simplify the accounting for income taxes by removing certain exceptions such as: 1) the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, 2) the requirement to recognize a deferred tax liability for equity method investments when a foreign subsidiary becomes an equity method investment, 3) the ability not to recognize a deferred tax liability for a foreign subsidiary when a foreign equity method investment becomes a subsidiary, and 4) the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. For public entities, the amendments are effective for reporting periods beginning after December 15, 2020. Early adoption is permitted. The application of this guidance will not have a material impact on the Companies’ financial position, results of operations and liquidity.

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 November 2020, LIBOR’s administrator announced it plans to consult on its intention to cease publication of one-week and two-month U.S. Dollar LIBOR immediately after the LIBOR publication on December 31, 2021, and the remaining U.S. Dollar LIBOR tenors immediately after publication on June 30, 2023. 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 from any date beginning March 12, 2020. 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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Acquisitions, Investments and Dispositions

12 Months Ended

Dec. 31, 2020

Business Combinations [Abstract]

Acquisitions, Investments and Dispositions

Acquisitions and Investments

Sempra Solar

In December 2018, the Clean Energy Businesses completed their acquisition of Sempra Solar Holdings, LLC, a Sempra Energy subsidiary, for $1,609 million, including working capital and other closing adjustments of $69 million. In 2019, Con Edison finalized the purchase price allocation and reclassified approximately $100 million which primarily decreased property, plant and equipment and asset retirement obligations, the impact of which was not material to earnings. The reclassification was recorded within the one year available to finalize the purchase price allocation.

The acquired company has ownership interests in 981 megawatts (AC) of operating renewable electric production projects, including its 379 megawatts (AC) share of projects in which its subsidiaries had a 50 percent ownership interest (Acquired JV Interests) and the Clean Energy Businesses had the remaining ownership interests (Previously-Owned JV Interests), and certain development rights with respect to solar electric production and energy storage projects.

At the acquisition date, the acquired company’s subsidiaries had $1,354 million of tangible assets consisting mostly of property, plant and equipment, $878 million of intangible assets mostly arising from power purchase agreements, $4 million of other noncurrent assets, $568 million of project debt (including, in each case, amounts associated with the Acquired JV Interests) and $28 million of asset retirement obligation liabilities. The weighted average amortization period for these intangible assets is 16 years. At the acquisition date, the fair value of the noncontrolling interest attributable to the tax equity investors (see below) was $100 million. The acquisition date valuation was performed using a discounted cash flow approach. The fair values of assets acquired and liabilities assumed were determined based on significant estimates and assumptions that are judgmental in nature, including projected amounts and timing of future cash flows, discount rates reflecting risk inherent in the future cash flows and future power prices.

Upon completion of the acquisition, the acquisition date fair value of the Previously-Owned JV Interests increased from $437 million to $568 million and Con Edison recognized a pre-tax gain of $131 million ($89 million or $0.28 per share net of taxes). Prior to the acquisition, Con Edison had been accounting for the Previously-Owned JV Interests under the equity method. Upon completion of the acquisition, Con Edison is accounting for Acquired JV Interests and the Previously-Owned JV Interests on a consolidated basis.

Certain projects acquired have tax equity investors to which a percentage of earnings, tax attributes and cash flows are allocated. See Note R.

Con Edison's revenues and net income for the years ended December 31, 2018 and 2017 as reported and pro forma to account on a consolidated basis for the acquisition as if the acquisition had been completed on January 1, 2017 instead of December 13, 2018 are as follows:

	Years ended December 31,
(Millions of Dollars)	2018	2017
As Reported
Revenue	$12,337	$12,033
Net income	1,382	1,525
PRO FORMA SUPPLEMENTAL INFORMATION
If Acquired January 1, 2017 (a)(b)
Revenue	$12,655	$12,331
Net income	1,279	1,612

(a) Reflects the following material adjustments:

•included additional interest expense of $37 million and $38 million in 2018 and 2017, respectively, that would have been incurred if $825 million that was borrowed in December 2018 under a variable rate term loan agreement to fund a portion of the purchase price for the acquisition had instead been borrowed for such purpose on January 1, 2017 at a fixed rate of 4.64% per annum; and

•with respect to the Previously-Owned JV Interests: eliminated the $131 million purchase accounting gain (pre-tax) that Con Edison recognized upon the completion of the acquisition in 2018 and reflected the $131 million purchase accounting gain in 2017; recorded the corresponding increase to the book value of the related net utility plant and power purchase agreement intangible asset as of January 1, 2017 instead of December 13, 2018, and included the increased depreciation and amortization expense in 2018 and 2017; and eliminated $33 million and $32 million of other income that Con Edison had recorded in 2018 and 2017, respectively, under the equity method of accounting.

(b) Recalculating each investor’s claim on the investee’s assets under the contractual liquidation waterfall as if the acquisition had been completed on January 1, 2017 is impracticable. Accordingly, no HLBV adjustments were made.

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Schedule I - Condensed Financial Information

12 Months Ended

Dec. 31, 2020

Condensed Financial Information Disclosure [Abstract]

Schedule I - Condensed Financial Information

Schedule I

Condensed Financial Information of Consolidated Edison, Inc. (a)

Condensed Statement of Income and Comprehensive Income

(Parent Company Only)

	For the Years Ended December 31,
(Millions of Dollars, except per share amounts)	2020	2019	2018
Equity in earnings of subsidiaries	$1,105	$1,354	$1,447
Other income (deductions), net of taxes	56	76	(6)
Interest expense	(60)	(87)	(59)
Net Income	$1,101	$1,343	$1,382
Comprehensive Income	$1,095	$1,340	$1,392
Net Income Per Share – Basic	$3.29	$4.09	$4.43
Net Income Per Share – Diluted	$3.28	$4.08	$4.42
Dividends Declared Per Share	$3.06	$2.96	$2.86
Average Number Of Shares Outstanding—Basic (In Millions)	334.8	328.5	311.1
Average Number Of Shares Outstanding—Diluted (In Millions)	335.7	329.5	312.9

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

Condensed Financial Information of Consolidated Edison, Inc. (a)

Condensed Statement of Cash Flows

(Parent Company Only)

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Net Income	1,101	1,343	1,382
Equity in earnings of subsidiaries	(1,105)	(1,354)	(1,447)
Dividends received from:
CECONY	982	912	846
O&R	49	47	46
Clean Energy Businesses	21	3	15
Con Edison Transmission	11	12	10
Change in Assets:
Special deposits	—	(3)	(8)
Income taxes receivable	—	25	2
Other – net	654	44	187
Net Cash Flows from Operating Activities	1,713	1,029	1,033
Investing Activities
Contributions to subsidiaries	(626)	(930)	(1,110)
Debt receivable from affiliated companies	400	450	(825)
Net Cash Flows Used in Investing Activities	(226)	(480)	(1,935)
Financing Activities
Net proceeds of short-term debt	(537)	(783)	164
Issuance of long-term debt	650	825	825
Retirement of long-term debt	(1,178)	(553)	(3)
Debt issuance costs	(3)	—	—
Issuance of common shares for stock plans, net of repurchases	58	54	53
Issuance of common shares - public offering	640	825	705
Common stock dividends	(975)	(924)	(842)
Net Cash Flows Used in Financing Activities	(1,345)	(556)	902
Net Change for the Period	142	(7)	—
Balance at Beginning of Period	2	9	9
Balance at End of Period	$144	$2	$9

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

Condensed Financial Information of Consolidated Edison, Inc. (a)

Condensed Balance Sheet

(Parent Company Only)

	December 31,
(Millions of Dollars)	2020	2019
Assets
Current Assets
Cash and temporary cash investments	$144	$2
Accounts receivable - other	1
Income taxes receivable	18	18
Term loan receivable from affiliated companies	—	—
Accounts receivable from affiliated companies	1,256	870
Prepayments	62	32
Other current assets	12	12
Total Current Assets	1,493	934
Investments in subsidiaries and others	18,670	18,009
Goodwill	406	406
Deferred income tax	55	14
Long-term debt receivable from affiliated companies	875	1,275
Other noncurrent assets	—	—
Total Assets	$21,499	$20,638
Liabilities and Shareholders’ Equity
Current Liabilities
Long-term debt due within one year	$1,178	$3
Term loan	—	—
Notes payable	—	537
Accounts payable	—	—
Accounts payable to affiliated companies	517	595
Accrued taxes	6	2
Other current liabilities	12	10
Total Current Liabilities	1,713	1,147
Deferred income tax	—	—
Total Liabilities	1,713	1,147
Long-term debt	939	1,469
Shareholders’ Equity
Common stock, including additional paid-in capital	8,844	8,089
Retained earnings	10,003	9,933
Total Shareholders’ Equity	18,847	18,022
Total Liabilities and Shareholders’ Equity	$21,499	$20,638

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

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Schedule II - Valuation and Qualifying Accounts

12 Months Ended

Dec. 31, 2020

SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]

Schedule II - Valuation and Qualifying Accounts

Schedule II

Valuation and Qualifying Accounts

For the Years Ended December 31, 2020, 2019 and 2018

				COLUMN C Additions
Company (Millions of Dollars)	COLUMN A Description		COLUMN B Balance at Beginning of Period	(1) Charged To Costs And Expenses	(2) Charged To Other Accounts	COLUMN D Deductions (b)	COLUMN E Balance At End of Period
Con Edison	Allowance for uncollectible accounts (a):
		2020	$74	$72	$—	$8	$154
		2019	$68	$77	$—	$(71)	$74
		2018	$70	$62	$—	$(64)	$68
CECONY	Allowance for uncollectible accounts (a):
		2020	$68	$65	$—	$10	$143
		2019	$61	$72	$—	$(65)	$68
		2018	$65	$56	$—	$(60)	$61

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

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

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Summary of Significant Accounting Policies and Other Matters (Policies)

12 Months Ended

Dec. 31, 2020

Accounting Policies [Abstract]

Principles of Consolidation

Principles of Consolidation

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

Accounting Policies

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.

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

The Utilities’ principal regulatory assets and liabilities are detailed in Note B. In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities at December 31, 2020 are recoverable from customers, or to be applied for customer benefit, in accordance with rate provisions that have been approved by state regulators.

Financial Instruments - Credit Losses

Financial Instruments – Credit Losses

Adoption of New Standard

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.” The amendments replace the incurred loss impairment methodology which involved delayed recognition of credit losses. The amendments introduce an expected credit loss impairment model which requires immediate recognition of anticipated losses over the instrument’s life. A broader range of reasonable and supportable information must be considered in developing the credit loss estimates. The Companies' financial instruments subject to the amendments are included in the lines “Accounts receivable – customers” and “Other receivables.” Substantially all of these in-scope financial instruments are expected to be collected within one year of billing.

The Companies adopted the amendments using the modified retrospective method for all financial instruments measured at amortized costs. Results for reporting periods beginning after January 1, 2020 are presented under Accounting Standards Codification (ASC) 326 while prior period amounts continue to be reported in accordance with previously applicable GAAP. No prior period adjustment or charge to retained earnings for cumulative impact was required as a result of the Companies’ adoption of the amendments.

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 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, 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.

During the year of 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 customer uncollectible accounts for Con Edison and CECONY were $78 million and $73 million, respectively, for the year ended December 31, 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.

Revenues

Revenues

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

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

Plant and Depreciation Utility Plant

Plant and Depreciation

Utility Plant

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

Rates used for AFUDC include the cost of borrowed funds and a reasonable rate of return on the Utilities’ own funds when so used, determined in accordance with regulations of the FERC or the state public utility regulatory authority having jurisdiction. The rate is compounded semiannually, and the amounts applicable to borrowed funds are treated as a reduction of interest charges, while the amounts applicable to the Utilities’ own funds are credited to other income (deductions). The AFUDC rates for CECONY were 5.2 percent, 5.1 percent and 5.4 percent for 2020, 2019 and 2018, respectively. The AFUDC rates for O&R were 5.3 percent, 5.3 percent and 2.2 percent for 2020, 2019 and 2018, respectively.

The Utilities generally compute annual charges for depreciation using the straight-line method for financial statement purposes, with rates based on average service lives and net salvage factors. The average depreciation rates for CECONY were 3.5 percent for 2020 and 3.2 percent for 2019 and 2018. The average depreciation rates for O&R were 3.2 percent for 2020, 3.0 percent for 2019 and 2.9 percent for 2018.

The estimated lives for utility plant for CECONY range from 5 to 85 years for electric, 5 to 90 years for gas, 5 to 80 years for steam and 5 to 55 years for general plant. For O&R, the estimated lives for utility plant range from 5 to 75 years for electric and gas and 5 to 50 years for general plant.

Non–Utility Plant

Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the Clean Energy Businesses’ renewable electric production projects. Property, plant and equipment are stated at cost, less accumulated depreciation and include capitalized interest during construction. Depreciation is computed under the straight-line method over the useful lives of the assets. Solar power generating assets and wind power generating assets have useful lives of 35 years and 30, respectively. For the Utilities, non-utility plant consists of land and conduit for telecommunication use. Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives, which is 10 years.

Other Deferred Charges and Noncurrent Assets and Prepayments

Other deferred charges and noncurrent assets and prepayments of Con Edison, net of accumulated depreciation, included $54 million ($51 million for CECONY) and $12 million ($11 million for CECONY), respectively at December 31, 2020, related to implementation costs incurred in cloud computing arrangements. The amounts recorded in 2019 were not material. Depreciation on these assets is computed using the straight-line method for financial statement purposes over their estimated useful lives. Depreciation expense related to these assets incurred during the year ended December 31, 2020 for Con Edison and CECONY was $7 million and $6 million, respectively. Accumulated depreciation related to these assets for Con Edison and CECONY was $10 million and $8 million, respectively at December 31, 2020 and was not material at December 31, 2019.

Long-Lived and Intangible Assets

Long–Lived and Intangible Assets

The Companies 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 carrying amount of a long-lived asset or intangible asset with a definite life is deemed not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the assets. In the event a test indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are considered impaired and written down to their estimated fair value.

Recoverable Energy Costs/New York Independent System Operator (NYISO)

Recoverable Energy Costs

The Utilities generally recover all of their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state public utility regulators. If the actual energy supply costs for a given month are more or less than the amounts billed to customers for that month,

the difference in most cases is recoverable from or refundable to customers. Differences between actual and billed electric and steam supply costs and costs of its electric demand management programs are generally deferred for charge or refund to customers during the next billing cycle (normally within one or two months). For the Utilities’ gas costs, differences between actual and billed gas costs during the 12-month period ending each August are charged or refunded to customers during a subsequent 12-month period.

New York Independent System Operator (NYISO)

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

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

Temporary Cash Investments

Temporary Cash Investments

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

Investments

Investments

Accounting for 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.

The accounting rules require Con Edison to periodically evaluate its investments 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 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 involves 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 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.

Con Edison evaluated its equity method investments and determined that there was an other-than-temporary decline in the value of its investment in Mountain Valley Pipeline LLC (MVP) and therefore recorded a partial impairment at December 31, 2020, as described below. Also, Con Edison is considering strategic alternatives with respect to its 50 percent interest in Stagecoach Gas Services, LLC (Stagecoach), a joint venture that owns and operates an existing gas pipeline and storage business located in northeastern Pennsylvania and the southern tier of New York. As such strategic alternatives are evaluated, Con Edison may be required to determine whether an other-than-temporary decline in value has occurred for its Stagecoach investment.

Partial Impairment of Investment in Mountain Valley Pipeline LLC (MVP)

In January 2016, Con Edison Gas Pipeline and Storage, LLC (CET Gas), an indirect subsidiary of Con Edison, acquired a 12.5 percent equity interest in MVP, a company developing a proposed gas transmission project (the Project) in West Virginia and Virginia. At December 31, 2020 and 2019, CET Gas' cash contributions to MVP were approximately $530 million, and the carrying value at December 31, 2020 prior to recording an impairment loss was

$662 million, reflecting CET Gas' proportionate share of allowance for funds used during construction (AFUDC) income from the Project. During 2019, Con Edison determined that, as it was permitted to do under the MVP joint venture agreement, it would limit its cash contributions to the joint venture to approximately $530 million, which limit was reached in 2019, and that is expected to result in the further reduction of Con Edison’s ownership share in the joint venture. At December 31, 2020, CET Gas owned an 11.3 percent interest in MVP that is expected to be reduced to 8.8 percent based on the current project cost estimate and CET Gas’ previous capping of its cash contributions to the joint venture.

During 2020, progress was made on the construction of the Project, and the U.S. Supreme Court issued favorable decisions in cases unrelated to MVP, regarding the permitting process for pipeline construction and water crossings. In November 2020, the U.S. Court of Appeals for the Fourth Circuit issued a stay on the Nationwide Permit 12, effectively blocking the Project’s ability to pursue water crossings under that permit. As a result, in November 2020 the Project applied to the FERC for a certificate amendment to bore under water bodies in the first 77 miles of the Project in West Virginia, allowing this portion of the pipe to be completed and placed in-service while a plan for the remaining water crossings was pursued. If approved, this amendment would lead to additional Project costs and would extend the anticipated in-service date of the Project to late 2021. The uncertainty related to obtaining the necessary permits in lieu of the Nationwide Permit 12, the resulting Project costs and the likelihood of the Project not reaching eventual completion have increased, constituting a triggering event which required Con Edison to test its investment in MVP for an other-than-temporary impairment as of December 31, 2020. Further, in January 2021, the FERC did not approve the requested amendment. In its discussion, a FERC commissioner indicated that the commission should have the plan for the entire Project’s water crossings rather than the first 77 miles and that all of the Federal permits be restored before allowing additional construction to resume. Later in January 2021, the Project indicated its plans to apply for U.S. Army Corps of Engineers individual permits for certain water crossings and a certificate amendment for other water crossings that, in total, would cover the entire Project length. In addition, the second largest partner in the Project announced it had recorded a significant impairment of their investment in the Project at year-end 2020.

In response to the triggering event, Con Edison assessed the value of its equity investment in the Project to determine whether the fair value of its investment in MVP had declined below its carrying value on an other-than-temporary basis. The estimated fair value of the investment was determined using a discounted cash flow analysis, which is a level 3 fair value measurement. The analysis discounted probability-weighted future cash flows, including revenues based on long-term firm transportation contracts, that are secured for the first 20 years following completion of the Project. See Note T. Con Edison has also assumed cash flows extending beyond this period. All cash flows were discounted at a pre-tax discount rate of 8.3 percent and then weighted based on Con Edison’s estimate of the likelihood that the Project will be completed. Con Edison believes that the likelihood of Project completion is in the upper end of a reasonably possible range. The likelihood that the Project is completed and the discount rate are the most significant and sensitive assumptions; changes in these assumptions may materially change the results of the impairment calculation.

Based on the discounted cash flow analysis, Con Edison concluded that the fair value of its investment in MVP declined below its carrying value and the decline is other-than-temporary. Accordingly, Con Edison recorded a pre-tax impairment loss of $320 million ($223 million, after tax), for the year ended December 31, 2020 to reduce the carrying value of its investment in MVP from $662 million to $342 million. The impairment was recorded within “Investment income (loss)” on Con Edison’s Consolidated Income Statement. In addition, Con Edison will not record non-cash equity in earnings from allowance for funds used during construction, if any, from MVP beginning in 2021 and until such time as substantial construction activities are resumed, which would be indicative of probable Project completion.

There is risk that the fair value of Con Edison’s investment in MVP may be further or fully impaired in the future. There are ongoing legal and regulatory matters that must be resolved favorably before the Project can be completed. Assumptions and estimates used to test Con Edison’s investment in MVP for impairment may change if adverse or delayed resolutions to the Project’s pending legal and regulatory challenges were to occur, which could have a material adverse effect on the fair value of Con Edison’s investment in MVP.

Pension and Other Postretirement Benefits

Pension and Other Postretirement Benefits

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

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

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

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

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

Federal Income Tax/State Income Tax

Federal Income Tax

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

Upon enactment of the Tax Cuts and Jobs Act of 2017 on December 22, 2017 (the TCJA), the Companies re-measured their deferred tax assets and liabilities based upon the 21 percent corporate income tax rate under the TCJA. The tax effects of changes in tax laws are to be recognized in the period in which the law is enacted and deferred tax assets and liabilities are to be re-measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. For the Utilities, in accordance with their New York rate plans and the accounting rules for regulated operations, the change in deferred taxes was recorded as either an offset to a regulatory asset or a regulatory liability. For Con Edison’s other businesses, the change in deferred taxes was reflected as a decrease in income tax expense, which increased Con Edison's net income. See “Other Regulatory Matters” and “Regulatory Assets and Liabilities” in Note B and Note L.

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

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

State Income Tax

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

Research and Development Costs

Research and Development CostsResearch and development costs are charged to operating expenses as incurred.

Reclassification

Reclassification

Certain prior year amounts have been reclassified within Note L to conform with current year 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 are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.

Potentially dilutive securities for Con Edison consist of restricted stock units and deferred stock units for which the average market price of the common shares for the period was greater than the exercise price (see Note N) and its common shares that are subject to forward sale agreements (see Note C). Before the issuance of common shares upon settlement of the forward sale agreements, the shares will be reflected in the company’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of common shares used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreements over the number of shares that could be purchased by the company in the market (based on the average market price during the period) using the proceeds due upon physical settlement (based on the adjusted forward sale price at the end of the reporting period).

Estimates

Estimates

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

New Financial Accounting Standards

New Financial Accounting Standards

In December 2019, the FASB issued amendments to the guidance for income taxes through ASU 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” The amendments in this update simplify the accounting for income taxes by removing certain exceptions such as: 1) the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, 2) the requirement to recognize a deferred tax liability for equity method investments when a foreign subsidiary becomes an equity method investment, 3) the ability not to recognize a deferred tax liability for a foreign subsidiary when a foreign equity method investment becomes a subsidiary, and 4) the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. For public entities, the amendments are effective for reporting periods beginning after December 15, 2020. Early adoption is permitted. The application of this guidance will not have a material impact on the Companies’ financial position, results of operations and liquidity.

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 November 2020, LIBOR’s administrator announced it plans to consult on its intention to cease publication of one-week and two-month U.S. Dollar LIBOR immediately after the LIBOR publication on December 31, 2021, and the remaining U.S. Dollar LIBOR tenors immediately after publication on June 30, 2023. 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 from any date beginning March 12, 2020. 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)

12 Months Ended

Dec. 31, 2020

Accounting Policies [Abstract]

Accounts Receivable, Allowance for Credit Loss

The table below presents a rollforward by major portfolio segment type for the year ended December 31, 2020:

	For the Year Ended December 31, 2020
	Con Edison		CECONY
(Millions of Dollars)	Accounts receivable - customers	Other receivables	Accounts receivable - customers	Other receivables
Allowance for credit losses
Beginning Balance at January 1, 2020	$70	$4	$65	$3
Recoveries	8	—	6	—
Write-offs	(54)	(2)	(50)	(1)
Reserve adjustments	124	5	117	2
Ending Balance December 31, 2020	$148	$7	$138	$4

Schedule of Total Excise Taxes Recorded in Operating Revenues

Total excise taxes (inclusive of gross receipts taxes) recorded in operating revenues were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$335	$323	$330
CECONY	323	312	318

Capitalized Cost of Utility Plant

At December 31, 2020 and 2019, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Electric
Generation	$572	$591	$572	$591
Transmission	3,786	3,634	3,496	3,380
Distribution	21,481	20,676	20,366	19,602
General	52	43	52	43
Gas (a)	9,206	8,617	8,522	7,961
Steam	1,854	1,813	1,854	1,813
General	2,507	2,365	2,286	2,143
Held for future use	92	75	84	67
Construction work in progress	2,474	1,937	2,320	1,812
Net Utility Plant	$42,024	$39,751	$39,552	$37,412

(a) Primarily distribution.

Schedule of Investment Assets

The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2020 and 2019:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
CET Gas investment in Stagecoach Gas Services, LLC	$845	$924	$—	$—
CET Gas investment in Mountain Valley Pipeline, LLC (a)	342	602	—	—
Supplemental retirement income plan assets (b)	465	397	439	371
Deferred income plan assets	92	81	92	81
CET Electric investment in New York Transco, LLC	69	59	—	—
Other	3	2	10	9
Total investments	$1,816	$2,065	$541	$461

(a)At December 31, 2020 and 2019, CET Gas' cash investment in MVP was $530 million. In January 2021, the operator of the Mountain Valley Pipeline indicated that, subject to receipt of certain authorizations and resolution of certain challenges, it is continuing to target an in-service date for the Project of late 2021 at an overall Project cost of $5,800 million to $6,000 million, excluding allowance for funds used during construction. For the year ended December 31, 2020, CET Gas owned an 11.3 percent interest in MVP and reduced the carrying value of its investment in MVP from $662 million to $342 million by recognizing a noncash impairment loss of $320 million, pre-tax ($223 million, after tax), and based on total estimated Project costs and CET Gas’ previous capping of its cash contributions to the joint venture, its ownership interest in the joint venture is expected to be reduced to 8.8%.

(b)See Note E.

Research and Development Costs

Research and development costs were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$24	$24	$24
CECONY	23	23	23

Basic and Diluted EPS

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

	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2020	2019	2018
Net income for common stock	$1,101	$1,343	$1,382
Weighted average common shares outstanding – basic	334.8	328.5	311.7
Add: Incremental shares attributable to effect of potentially dilutive securities	0.9	1.0	1.2
Adjusted weighted average common shares outstanding – diluted	335.7	329.5	312.9
Net Income per common share – basic	$3.29	$4.09	$4.43
Net Income per common share – diluted	$3.28	$4.08	$4.42

Changes in Accumulated Other Comprehensive Income/(Loss)

Changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:

(Millions of Dollars)	Con Edison	CECONY
Accumulated OCI, net of taxes, at December 31, 2017 (a)	$(26)	$(6)
OCI before reclassifications, net of tax of $3 for Con Edison	4	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	6	1
Total OCI, net of taxes, at December 31, 2018	10	1
Accumulated OCI, net of taxes, at December 31, 2018 (a)	$(16)	$(5)
OCI before reclassifications, net of tax of $(6) and $(1) for Con Edison and CECONY, respectively	(10)	(3)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	7	2
Total OCI, net of taxes, at December 31, 2019	(3)	(1)
Accumulated OCI, net of taxes, at December 31, 2019 (a)	$(19)	$(6)
OCI before reclassifications, net of tax of $4 and $1 for Con Edison and CECONY, respectively	(11)	(3)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison (a)(b)	5	2
Total OCI, net of taxes, at December 31, 2020	(6)	(1)
Accumulated OCI, net of taxes, at December 31, 2020 (a)	$(25)	$(7)

(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 cost. See Notes E and F.

Restrictions on Cash and Cash Equivalents

At December 31, 2020 and 2019, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows:

	At December 31,
	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Cash and temporary cash investments	$1,272	$981	$1,067	$933
Restricted cash (a)	164	236	—	—
Total cash, temporary cash investments and restricted cash	$1,436	$1,217	$1,067	$933

(a)Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($164 million and $236 million at December 31, 2020 and 2019, respectively) that, under the related project debt agreements, is either restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves or, for the December 31, 2019 amount, was restricted as a result of the PG&E bankruptcy. During the pendency of the PG&E bankruptcy, cash was not distributed from the related projects to the Clean Energy Businesses. In July 2020, PG&E's plan of reorganization became effective and the Clean Energy Businesses received previously restricted distributions and have resumed receiving distributions for all projects. See "Long-Lived and Intangible Assets,” above.

Schedule of Cash and Cash Equivalents

At December 31, 2020 and 2019, cash, temporary cash investments and restricted cash for Con Edison and CECONY were as follows:

	At December 31,
	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Cash and temporary cash investments	$1,272	$981	$1,067	$933
Restricted cash (a)	164	236	—	—
Total cash, temporary cash investments and restricted cash	$1,436	$1,217	$1,067	$933

(a)Restricted cash included cash of the Clean Energy Businesses' renewable electric production project subsidiaries ($164 million and $236 million at December 31, 2020 and 2019, respectively) that, under the related project debt agreements, is either restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves or, for the December 31, 2019 amount, was restricted as a result of the PG&E bankruptcy. During the pendency of the PG&E bankruptcy, cash was not distributed from the related projects to the Clean Energy Businesses. In July 2020, PG&E's plan of reorganization became effective and the Clean Energy Businesses received previously restricted distributions and have resumed receiving distributions for all projects. See "Long-Lived and Intangible Assets,” above.

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Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2020

Regulated Operations [Abstract]

Summary of Utilities Rate Plans

The following tables contain a summary of the Utilities’ rate plans:

CECONY – Electric
Effective period	January 2017 – December 2019	January 2020 – December 2022 (a)
Base rate changes	Yr. 1 – $195 million (b) Yr. 2 – $155 million (b) Yr. 3 – $155 million (b)	Yr. 1 – $113 million (c) Yr. 2 – $370 million (c) Yr. 3 – $326 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million	Yr. 1 – $267 million (d) Yr. 2 – $269 million (d) Yr. 3 – $272 million (d)
Other revenue sources	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, 2018 and 2019, the company recorded $13 million, $25 million and $43 million of earnings adjustment mechanism incentives for energy efficiency, respectively. The company also achieved $5 million of incentives for service terminations in 2017, 2018 and 2019 that, pursuant to the rate plan, is being recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded $3 million and $7 million of incentives for service terminations, respectively.	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020, the company recorded $34 million primarily related to earnings adjustment mechanism incentives for energy efficiency.
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, 2018 and 2019, the company deferred for customer benefit $45 million, $(6) million and $169 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, the company deferred for recovery from customers $242 million of revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased power and fuel 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 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017 and 2018, the company did not record any negative revenue adjustments. In 2019, the company recorded negative revenue adjustments of $15 million.	Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (g). In 2017, 2018 and 2019, the company deferred $35 million, $189 million and $10 million of net regulatory assets, respectively.	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2020, the company deferred $288 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017. In 2018 and 2019, $0.4 and $11.8 million was deferred as a regulatory liability, respectively.	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI: Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million (h) The company deferred $4.1 million as a regulatory asset in 2020.
Average rate base	Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million	Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent	6.61 percent
Authorized return on common equity	9.0 percent	8.80 percent

Actual return on common equity (i)	Yr. 1 – 9.30 percent Yr. 2 – 9.36 percent Yr. 3 – 8.82 percent	Yr. 1 – 8.50 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings. In 2018 and 2019, the company had no earnings sharing above the threshold.	Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, the company had no earnings sharing above the threshold.
Cost of long-term debt	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent	4.63 percent
Common equity ratio	48 percent	48 percent

(a)In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's electric rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note T) are not necessary.

(b)The electric base rate increases were in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases were implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a 10-year period, including the overall pre-tax rate of return on such costs.

(c)Base rates reflect recovery by the company of certain costs of its energy efficiency, Reforming the Energy Vision demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d)Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually).

(e)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.

(f)In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of

30 percent of the amount reflected in the January 2017-December 2019 rate plan and 15 percent of the amount reflected in the January 2020-December 2022 rate plan.

(g)In addition, the NYSPSC staff has commenced a focused operations audit to investigate the income tax accounting of CECONY and other New York utilities. Any NYSPSC-ordered adjustment to CECONY’s income tax accounting will be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below.

(h)Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas.

(i)Calculated in accordance with the earnings calculation method prescribed in the rate order.

CECONY – Gas
Effective period	January 2017 - December 2019	January 2020 – December 2022 (a)
Base rate changes	Yr. 1 – $(5) million (b) Yr. 2 – $92 million Yr. 3 – $90 million	Yr. 1 – $84 million (c) Yr. 2 – $122 million (c) Yr. 3 – $167 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million	Yr. 1 – $45 million (d) Yr. 2 – $43 million (d) Yr. 3 – $10 million (d)
Other revenue sources	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, 2018 and 2019, the company achieved incentives of $7 million, $6 million and $7 million, respectively, that, pursuant to the rate plan, was recorded ratably in earnings from 2018 to 2020. In 2018 and 2019, the company recorded incentives of $5 million and $9 million, respectively, for gas leak backlog, leak prone pipe and service terminations.	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $20 million Yr. 2 - $22 million Yr. 3 - $25 million In 2020, the company recorded $3 million of earnings adjustment mechanism incentives for energy efficiency. In 2020, the company recorded positive incentives of $13 million.
Revenue decoupling mechanisms	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, 2018 and 2019, the company deferred $3 million, $12 million and $10 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, the company deferred for recovery from customers $27 million of revenues.
Recoverable energy costs	Continuation of current rate recovery of purchased gas 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 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017 and 2018, the company recorded negative revenue adjustments of $5 million and $4 million, respectively. In 2019, the company did not record any negative revenue adjustments.	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $81 million Yr. 2 - $88 million Yr. 3 - $96 million In 2020, the company did not record any negative revenue adjustments.
Cost reconciliations	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2017, 2018 and 2019, the company deferred $2 million of net regulatory liabilities, $44 million of net regulatory assets and $18 million of net regulatory assets, respectively.	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (e), municipal infrastructure support costs (f), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (g) In 2020, the company deferred $91 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 and 2018 the company deferred $2.2 million as regulatory liabilities. In 2019, the company deferred $1.7 million as a regulatory liability.	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $8,108 million Yr. 2 - $8,808 million Yr. 3 - $9,510 million AMI: Yr. 1 - $142 million Yr. 2 - $183 million Yr. 3 - $211 million (h) In 2020, the company deferred $24.7 million as a regulatory liability.
Average rate base	Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million	Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million
Weighted average cost of capital (after-tax)	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent	6.61 percent
Authorized return on common equity	9.0 percent	8.80 percent
Actual return on common equity (i)	Yr. 1 – 9.22 percent Yr. 2 – 9.04 percent Yr. 3 – 8.72 percent	Yr. 1 – 8.40 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, 2018 and 2019, the company had no earnings above the threshold.	Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent	4.63 percent
Common equity ratio	48 percent	48 percent

(a)In January 2020, the NYSPSC approved the October 2019 Joint Proposal for CECONY's gas rate plan for January 2020 through December 2022. If at the end of any semi-annual period ending June 30 and December 31, Con Edison’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures (see Note T) are not necessary.

(b)The gas base rate decrease was offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(c)The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d)Amounts reflect amortization of the remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually)

(e)-(i)    See footnotes (e) - (i) to the table under “CECONY Electric,” above.

CECONY – Steam
Effective period	January 2014 – December 2016 (a)
Base rate changes	Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None
Amortizations to income of net regulatory (assets) and liabilities	$37 million over three years
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential charges (up to $1 million annually) if certain steam performance targets are not met. In years 2014 through 2020, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015, 2016, 2017, 2018, 2019 and 2020, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities and $35 million of net regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Production: Yr. 1 – $1,752 million Yr. 2 – $1,732 million Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million Yr. 2 – $11 million Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. The company reduced its regulatory liability by $1.6 million in 2020.
Average rate base	Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent
Authorized return on common equity	9.3 percent
Actual return on common equity (d)	Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent
Earnings sharing	Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent
Common equity ratio	48 percent

(a)Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC.

(b)The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016.

(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 10 basis point impact on return on common equity.

(d)Calculated in accordance with the earnings calculation method prescribed in the rate order.

O&R New York – Electric
Effective period	November 2015 - October 2017 (a)	January 2019 – December 2021 (d)
Base rate changes	Yr. 1 – $9.3 million Yr. 2 – $8.8 million Yr. 3 – None	Yr. 1 – $13.4 million (e) Yr. 2 – $8.0 million (e) Yr. 3 – $5.8 million (e)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 – $(8.5) million (b) Yr. 2 – $(9.4) million (b) Yr. 3 – None	Yr. 1 – $(1.5) million (f) Yr. 2 – $(1.5) million (f) Yr. 3 – $(1.5) million (f)
Other revenue sources		Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019 and 2020, the company recorded $2.6 million and $1.9 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively.
Revenue decoupling mechanisms	In 2015, 2016, 2017 and 2018, the company deferred for the customer’s benefit an immaterial amount, $6.3 million as regulatory liabilities, $11.2 million as regulatory asset and $0.5 million as regulatory asset, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million as regulatory assets.
Recoverable energy costs	Continuation of current rate recovery of purchased power costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential charges (up to $4 million annually) if certain performance targets are not met. In 2015 the company recorded $1.25 million in negative revenue adjustments. In 2016, 2017 and 2018, the company did not record any negative revenue adjustments.	Potential charges if certain performance targets relating to service, reliability and other matters are not met: Yr. 1 - $4.4 million Yr. 2 - $4.4 million Yr. 3 - $4.5 million In 2019 and 2020, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2015, 2016 and 2017, the company deferred $0.3 million, $7.4 million and $3.2 million as net decreases to regulatory assets, respectively. In 2018, the company deferred $5 million as a net regulatory asset.	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), major storms, the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $4.3 million and $30.3 million as net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates are: Yr. 1 – $928 million (c) Yr. 2 – $970 million (c) The company increased/(reduced) its regulatory asset by $2.2 million, $(1.9) million, $(1.9) million and $1.4 million in 2015, 2016, 2017 and 2018, respectively.	Target levels reflected in rates were: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $1,008 million Yr. 2 - $1,032 million Yr. 3 - $1,083 million AMI (j): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019 and deferred $0.4 million as a regulatory liability in 2020.
Average rate base	Yr. 1 – $763 million Yr. 2 – $805 million Yr. 3 – $805 million	Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent	Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent
Authorized return on common equity	9.0 percent	9.0 percent
Actual return on common equity (k)	Yr. 1 – 10.8 percent Yr. 2 – 9.7 percent Yr. 3 – 7.2 percent	Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $6.1 million, $0.3 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold.
Cost of long-term debt	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent	Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent
Common equity ratio	48 percent	48 percent

(a)Rates determined pursuant to this rate plan continued in effect until the subsequent rate plan became effective.

(b)$59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a 5 year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015.

(c)Excludes electric AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2.

(d)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 (see Note T) are not necessary.

(e)The electric base rate increases shown above will be implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million.

(f)Reflects amortization of, among other things, the company’s net benefits under the TCJA prior to January 1, 2019, amortization of net regulatory liability for future income taxes and reduction of previously incurred regulatory assets for environmental remediation costs. Also, for electric, reflects amortization over a six year period of previously incurred incremental major storm costs. See "Other Regulatory Matters," below.

(g)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.

(h)Energy efficiency costs are expensed as incurred. Such costs are subject to a downward-only reconciliation over the terms of the electric and gas rate plans. The company will defer for the benefit of customers any cumulative shortfall over the terms of the electric and gas rate plans between actual expenditures and the levels provided in rates.

(i)In addition, amounts reflected in rates relating to income taxes and excess deferred federal income tax liability balances will be reconciled (i.e., refunded to or collected from customers) to any final, non-appealable NYSPSC-ordered findings in its investigation of O&R’s income tax accounting. See “Other Regulatory Matters,” in Note B.

(j)Net plant reconciliation for AMI expenditures will be implemented for a single category of AMI capital expenditures that includes amounts allocated to both electric and gas customers.

(k)Calculated in accordance with the earnings calculation method prescribed in the rate order.

In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective January 1, 2022, of $24.5 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased power, and the reconciliation of actual expenses allocable to the electric business to the amounts for such costs reflected in electric rates for storm costs, pension and other postretirement benefit costs, environmental remediation and property taxes.

O&R New York – Gas
Effective period	November 2015 – October 2018 (a)	January 2019 – December 2021 (d)
Base rate changes	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge	Yr. 1 – $(7.5) million (e) Yr. 2 – $3.6 million (e) Yr. 3 – $0.7 million (e)
Amortization to income of net regulatory (assets) and liabilities	Yr. 1 – $(1.7) million (b) Yr. 2 – $(2.1) million (b) Yr. 3 – $(2.5) million (b)	Yr. 1 – $1.8 million (f) Yr. 2 – $1.8 million (f) Yr. 3 – $1.8 million (f)
Other revenue sources		Continuation of retention of annual revenues from non-firm customers of up to $4.0 million, with variances to be shared 80 percent by customers and 20 percent by company. Potential earnings adjustment mechanism incentives of up to $0.3 million annually. Potential incentives if performance targets related to gas leak backlog, leak prone pipe, emergency response, damage prevention and customer service are met: Yr. 1 - $1.2 million; Yr. 2 - $1.3 million; and Yr. 3 - $1.3 million. In 2019 and 2020, the company recorded $0.3 million of earnings adjustment mechanism incentives for energy efficiency. In 2019 and 2020, the company recorded $0.7 million and $0.5 million of positive incentives, respectively.
Revenue decoupling mechanisms	In 2015, 2016, 2017 and 2018, the company deferred $0.8 million of regulatory assets, $6.2 million of regulatory liabilities, $1.7 million of regulatory liabilities and $6.3 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2019 and 2020, the company deferred $0.8 million and $0.5 million of regulatory assets, respectively.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential charges (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $4.9 million in Yr. 3) if certain performance targets are not met. In 2015, 2016 and 2017, the company did not record any negative revenue adjustments. In 2018, the company recorded a $0.1 million negative revenue adjustment.	Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $5.5 million; Yr. 2 - $5.7 million; and Yr. 3 - $6.0 million. In 2019 and 2020, the company recorded a $0.2 million and an immaterial amount of negative revenue adjustments, respectively.
Cost reconciliations	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively. In 2017 and 2018, the company deferred $3.5 million and $7.4 million as net regulatory liabilities, respectively.	Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (g), energy efficiency program (h), the impact of new laws and certain other costs to amounts reflected in rates.(i) In 2019 and 2020, the company deferred $6 million as net regulatory liabilities and $1.8 million as net regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates are: Yr. 1 – $492 million (c) Yr. 2 – $518 million (c) Yr. 3 – $546 million (c) No deferral was recorded for 2015 and immaterial amounts were recorded as regulatory liabilities in 2016 and 2017. In 2018, the company deferred $0.4 million as regulatory asset.	Target levels reflected in rates were: Gas average net plant target excluding AMI: Yr. 1 - $593 million Yr. 2 - $611 million Yr. 3 - $632 million AMI (j): Yr. 1 - $20 million Yr. 2 - $24 million Yr. 3 - $25 million In 2019 and 2020, the company deferred immaterial amounts as regulatory assets.
Average rate base	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million	Yr. 1 – $454 million Yr. 2 – $476 million Yr. 3 – $498 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent	Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent
Authorized return on common equity	9.0 percent	9.0 percent
Actual return on common equity (k)	Yr. 1 – 11.2 percent Yr. 2 – 9.7 percent Yr. 3 – 8.1 percent	Yr. 1 – 8.90 percent Yr. 2 – 9.58 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million, $0.2 million above the threshold for 2016 and 2017, respectively. In 2018, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold.
Cost of long-term debt	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent	Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent
Common equity ratio	48 percent	48 percent

(a)Rates pursuant to this rate plan continued in effect until the subsequent rate plan became effective.

(b)Reflects that the company will not recover from customers a total of approximately $14 million of regulatory assets for property tax and interest rate reconciliations. Amounts that will not be recovered from customers were charged-off in June 2015.

(c)Excludes gas AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $0.5 million in year 1, $4.2 million in year 2 and $7.2 million in year 3.

(d)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 (see Note T) are not necessary.

(e)The gas base rate changes shown above will be implemented with changes of: Yr. 1 - $(5.9) million; Yr. 2 - $1.0 million; and Yr. 3 - $1.0 million.

(f)-(k) See footnotes (f) - (k) to the table under “O&R New York - Electric,” above.

In January 2021, O&R filed a request with the NYSPSC for an increase in the rates it charges for gas service rendered in New York, effective January 1, 2022, of $9.8 million. The filing reflects a return on common equity of 9.5 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased gas, and the reconciliation of actual expenses allocable to the gas business to the amounts for such costs reflected in gas rates for pension and other postretirement benefit costs, environmental remediation and property taxes.

In January 2020, the NJBPU approved an electric rate increase, effective February 1, 2020, of $12 million for RECO. The following table contains a summary of the terms of the distribution rate plans.

RECO
Effective period	March 2017 – January 2020	February 2020
Base rate changes	Yr. 1 – $1.7 million	Yr. 1 – $12 million
Amortization to income of net regulatory (assets) and liabilities	$0.2 million over three years and continuation of $(25.6) million of deferred storm costs over four years which expired on July 31, 2018 (a)	$4.8 million over four years.
Recoverable energy costs	Current rate recovery of purchased power costs.	Current rate recovery of purchased power costs.
Cost reconciliations	None	None
Average rate base	Yr. 1 – $178.7 million	Yr. 1 – $229.9 million
Weighted average cost of capital (after-tax)	7.47 percent	7.11 percent
Authorized return on common equity	9.6 percent	9.5 percent
Actual return on common equity	Yr. 1 – 7.5 percent Yr. 2 – 5.7 percent	Yr. 1 – 5.4 percent
Cost of long-term debt	5.37 percent	4.88 percent
Common equity ratio	49.7 percent	48.32 percent

(a)In January 2016, the NJBPU approved RECO’s plan to spend $15.7 million in capital over three years to harden its electric system against storms, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge.

Schedule of Regulatory Assets

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2020 and 2019 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Regulatory assets
Unrecognized pension and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	865	732	791	647
Revenue taxes	356	321	342	308
Pension and other postretirement benefits deferrals	315	71	272	47
Property tax reconciliation	241	219	239	210
Deferred storm costs	195	77	83	—
MTA power reliability deferral	188	248	188	248
System peak reduction and energy efficiency programs	124	131	124	130
Deferred derivative losses	120	83	111	76
COVID - 19 Deferrals	115	—	113	—
Municipal infrastructure support costs	62	75	62	75
Brooklyn Queens demand management program	36	39	36	39
Meadowlands heater odorization project	32	35	32	35
Gate station upgrade project	25	19	25	19
Unamortized loss on reacquired debt	21	28	19	26
Preferred stock redemption	21	22	21	22
Recoverable REV demonstration project costs	20	21	18	19
Non-wire alternative projects	18	14	18	14
Workers’ compensation	—	3	—	3
Other	200	180	186	166
Regulatory assets – noncurrent	6,195	4,859	5,745	4,487
Deferred derivative losses	190	128	177	113
Recoverable energy costs	76	—	67	—
Regulatory assets – current	266	128	244	113
Total Regulatory Assets	$6,461	$4,987	$5,989	$4,600
Regulatory liabilities
Future income tax*	$2,207	$2,426	$2,062	$2,275
Allowance for cost of removal less salvage	1,090	989	932	843
TCJA net benefits	295	471	286	454
Net unbilled revenue deferrals	198	199	198	199
Net proceeds from sale of property	137	173	137	173
Pension and other postretirement benefit deferrals	85	75	46	46
System benefit charge carrying charge	64	48	57	44
Property tax refunds	36	45	35	45
BQDM and REV Demo reconciliations	27	27	25	26
Settlement of gas proceedings	21	10	21	10
Sales and use tax refunds	16	8	16	8
Earnings sharing - electric, gas and steam	15	22	10	15
Unrecognized other postretirement costs	11	9	—	—
Settlement of prudence proceeding	5	8	5	8
Workers’ compensation	3	—	3	—
Energy efficiency portfolio standard unencumbered funds	1	122	—	118
Other	302	195	261	163
Regulatory liabilities – noncurrent	4,513	4,827	4,094	4,427
Refundable energy costs	28	44	4	12
Deferred derivative gains	8	34	7	34
Revenue decoupling mechanism	—	24	—	17
Regulatory liabilities—current	36	102	11	63
Total Regulatory Liabilities	$4,549	$4,929	$4,105	$4,490

* See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.

Schedule of Regulatory Liabilities

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2020 and 2019 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Regulatory assets
Unrecognized pension and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	865	732	791	647
Revenue taxes	356	321	342	308
Pension and other postretirement benefits deferrals	315	71	272	47
Property tax reconciliation	241	219	239	210
Deferred storm costs	195	77	83	—
MTA power reliability deferral	188	248	188	248
System peak reduction and energy efficiency programs	124	131	124	130
Deferred derivative losses	120	83	111	76
COVID - 19 Deferrals	115	—	113	—
Municipal infrastructure support costs	62	75	62	75
Brooklyn Queens demand management program	36	39	36	39
Meadowlands heater odorization project	32	35	32	35
Gate station upgrade project	25	19	25	19
Unamortized loss on reacquired debt	21	28	19	26
Preferred stock redemption	21	22	21	22
Recoverable REV demonstration project costs	20	21	18	19
Non-wire alternative projects	18	14	18	14
Workers’ compensation	—	3	—	3
Other	200	180	186	166
Regulatory assets – noncurrent	6,195	4,859	5,745	4,487
Deferred derivative losses	190	128	177	113
Recoverable energy costs	76	—	67	—
Regulatory assets – current	266	128	244	113
Total Regulatory Assets	$6,461	$4,987	$5,989	$4,600
Regulatory liabilities
Future income tax*	$2,207	$2,426	$2,062	$2,275
Allowance for cost of removal less salvage	1,090	989	932	843
TCJA net benefits	295	471	286	454
Net unbilled revenue deferrals	198	199	198	199
Net proceeds from sale of property	137	173	137	173
Pension and other postretirement benefit deferrals	85	75	46	46
System benefit charge carrying charge	64	48	57	44
Property tax refunds	36	45	35	45
BQDM and REV Demo reconciliations	27	27	25	26
Settlement of gas proceedings	21	10	21	10
Sales and use tax refunds	16	8	16	8
Earnings sharing - electric, gas and steam	15	22	10	15
Unrecognized other postretirement costs	11	9	—	—
Settlement of prudence proceeding	5	8	5	8
Workers’ compensation	3	—	3	—
Energy efficiency portfolio standard unencumbered funds	1	122	—	118
Other	302	195	261	163
Regulatory liabilities – noncurrent	4,513	4,827	4,094	4,427
Refundable energy costs	28	44	4	12
Deferred derivative gains	8	34	7	34
Revenue decoupling mechanism	—	24	—	17
Regulatory liabilities—current	36	102	11	63
Total Regulatory Liabilities	$4,549	$4,929	$4,105	$4,490

* See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.

Schedule Of Regulatory Assets Not Earning Return

Regulatory Assets Not Earning a Return

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Unrecognized and other postretirement costs	$3,241	$2,541	$3,065	$2,403
Environmental remediation costs	855	727	781	647
Revenue taxes	336	296	323	285
Deferred derivative losses	120	83	111	76
Workers' compensation	—	3	—	3
Other	24	21	24	20
Deferred derivative losses - current	190	128	177	112
Total	4,766	3,799	4,481	3,546

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Capitalization (Tables)

12 Months Ended

Dec. 31, 2020

Debt Disclosure [Abstract]

Schedule of Long-Term Debt Maturities

Long-term debt maturing in the period 2021-2025 is as follows:

(Millions of Dollars)	Con Edison	CECONY
2021	$1,967	$640
2022	437	—
2023	966	—
2024	385	250
2025	315	—

Carrying Amounts and Fair Values of Long-Term Debt

The carrying amounts and fair values of long-term debt at December 31, 2020 and 2019 are:

(Millions of Dollars)	2020		2019
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$22,349	$26,808	$19,973	$22,738
CECONY	$16,789	$20,974	$14,964	$17,505

(a)Amounts shown are net of unamortized debt expense and unamortized debt discount of $215 million and $176 million for Con Edison and CECONY, respectively, as of December 31, 2020 and $178 million and $151 million for Con Edison and CECONY, respectively, as of December 31, 2019.

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Pension Benefits (Tables)

12 Months Ended

Dec. 31, 2020

Retirement Benefits [Abstract]

Total Periodic Benefit Costs

The components of the Companies’ total periodic benefit costs for 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Service cost – including administrative expenses	$293	$250	$290	$274	$232	$272
Interest cost on projected benefit obligation	549	601	561	515	564	525
Expected return on plan assets	(1,034)	(988)	(1,033)	(980)	(936)	(979)
Recognition of net actuarial loss	699	518	688	661	492	651
Recognition of prior service credit	(16)	(17)	(17)	(19)	(19)	(19)
TOTAL PERIODIC BENEFIT COST	$491	$364	$489	$451	$333	$450
Cost capitalized	(130)	(108)	(127)	(123)	(102)	(119)
Reconciliation to rate level	(250)	(15)	(92)	(239)	(12)	(100)
Total expense recognized	$111	$241	$270	$89	$219	$231

The components of the Companies’ total periodic postretirement benefit costs for 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Service cost	$21	$18	$20	$16	$13	$14
Interest cost on accumulated other postretirement benefit obligation	37	44	42	31	36	34
Expected return on plan assets	(66)	(66)	(73)	(54)	(54)	(63)
Recognition of net actuarial loss/(gain)	37	(9)	8	36	(10)	3
Recognition of prior service credit	(3)	(2)	(6)	(2)	(2)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	$26	$(15)	$(9)	$27	$(17)	$(14)
Cost capitalized	(9)	(7)	(8)	(7)	(5)	(6)
Reconciliation to rate level	(17)	12	8	(25)	7	9
Total credit recognized	$—	$(10)	($9)	$(5)	$(15)	($11)

Schedule of Funded Status

The funded status at December 31, 2020, 2019 and 2018 was as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$16,792	$14,449	$15,536	$15,750	$13,542	$14,567
Service cost – excluding administrative expenses	288	245	286	269	228	267
Interest cost on projected benefit obligation	549	601	561	515	564	525
Net actuarial loss/(gain)	2,281	2,191	(1,219)	2,154	2,076	(1,159)
Plan amendments	—	15	—	—	—	—
Benefits paid	(945)	(709)	(715)	(867)	(660)	(658)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$18,965	$16,792	$14,449	$17,821	$15,750	$13,542
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$15,608	$13,450	$14,274	$14,790	$12,744	$13,519
Actual return on plan assets	1,927	2,556	(536)	1,830	2,425	(507)
Employer contributions	475	350	473	435	318	434
Benefits paid	(945)	(709)	(715)	(867)	(660)	(658)
Administrative expenses	(43)	(39)	(46)	(41)	(37)	(44)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$17,022	$15,608	$13,450	$16,147	$14,790	$12,744
FUNDED STATUS	$(1,943)	$(1,184)	$(999)	$(1,674)	$(960)	$(798)
Unrecognized net loss	$3,330	$2,604	$2,464	$3,145	$2,466	$2,338
Unrecognized prior service costs/(credits)	(156)	(173)	(205)	(183)	(202)	(222)
Accumulated benefit obligation	16,768	15,015	13,030	15,676	14,010	12,161

The funded status of the programs at December 31, 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$1,357	$1,114	$1,219	$1,154	$913	$985
Service cost	21	18	20	16	13	14
Interest cost on accumulated postretirement benefit obligation	37	44	42	31	36	34
Amendments	—	(14)	—	—	—	—
Net actuarial loss/(gain)	74	264	(70)	63	252	(32)
Benefits paid and administrative expenses, net of subsidies	(117)	(110)	(135)	(107)	(100)	(125)
Participant contributions	53	41	38	52	40	37
BENEFIT OBLIGATION AT END OF YEAR	$1,425	$1,357	$1,114	$1,209	$1,154	$913
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$1,026	$885	$1,039	$872	$759	$893
Actual return on plan assets	142	198	(66)	117	165	(54)
Employer contributions	7	7	6	4	6	6
Employer group waiver plan subsidies	20	23	34	19	22	32
Participant contributions	53	40	37	51	40	37
Benefits paid	(133)	(127)	(165)	(123)	(120)	(155)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$1,115	$1,026	$885	$940	$872	$759
FUNDED STATUS	$(310)	$(331)	$(229)	$(269)	$(282)	$(154)
Unrecognized net loss/(gain)	$115	$155	$14	$114	$149	$(2)
Unrecognized prior service costs	(16)	(19)	(8)	(1)	(3)	(5)

Schedule of Assumptions

The actuarial assumptions were as follows: 

	2020		2019		2018
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate	2.55	%	3.35	%	4.25	%
Interest crediting rate for cash balance plan	3.00	%	3.30	%	4.00	%
Rate of compensation increase
CECONY	3.80	%	3.80	%	4.25	%
O&R	3.20	%	3.20	%	4.00	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	3.35	%	4.25	%	3.70	%
Interest crediting rate for cash balance plan	3.30	%	4.00	%	4.10	%
Expected return on plan assets	7.00	%	7.00	%	7.50	%
Rate of compensation increase
CECONY	3.80	%	4.25	%	4.25	%
O&R	3.20	%	4.00	%	4.00	%

The actuarial assumptions were as follows: 

	2020		2019		2018
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY	2.25	%	3.10	%	4.15	%
O&R	2.55	%	3.35	%	4.30	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate
CECONY	3.10	%	4.15	%	3.55	%
O&R	3.35	%	4.30	%	3.70	%
Expected Return on Plan Assets	6.80	%	6.80	%	7.50	%

Schedule of Expected Benefit Payments

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

(Millions of Dollars)	2021	2022	2023	2024	2025	2026-2030
Con Edison	$764	$776	$793	$807	$821	$4,295
CECONY	706	718	733	747	760	3,992

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

(Millions of Dollars)	2021	2022	2023	2024	2025	2026-2030
Con Edison	$84	$84	$84	$84	$84	$409
CECONY	76	75	75	75	75	358

Schedule of Plan Assets Allocations

The asset allocations for the pension plan at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2021	2020		2019		2018
Equity Securities	45% - 55%	51	%	51	%	51	%
Debt Securities	33% - 43%	38	%	38	%	39	%
Real Estate	10% - 14%	11	%	11	%	10	%
Total	100%	100	%	100	%	100	%

The asset allocations for CECONY’s other postretirement benefit plans at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2021	2020		2019		2018
Equity Securities	42%-80%	54	%	54	%	52	%
Debt Securities	20%-58%	46	%	46	%	48	%
Total	100%	100	%	100	%	100	%

Schedule of Fair Value of Plan Assets

The fair values of the pension plan assets at December 31, 2020 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Investments within the fair value hierarchy
U.S. Equity (a)	$4,202	$—	$4,202
International Equity (b)	3,693	—	3,693
U.S. Government Issued Debt (c)	—	1,424	1,424
Corporate Bonds Debt (d)	—	3,535	3,535
Structured Assets Debt (e)	—	188	188
Other Fixed Income Debt (f)	—	1,067	1,067
Cash and Cash Equivalents (g)	51	408	459
Total investments within the fair value hierarchy	$7,946	$6,622	$14,568
Investments measured at NAV per share (m)
Private Equity (h)			635
Real Estate (i)			1,880
Hedge Funds (j)			292
Total investments valued using NAV per share			$2,807
Funds for retiree health benefits (k)	(116)	(97)	(213)
Funds for retiree health benefits measured at NAV per share (k)(m)			(41)
Total funds for retiree health benefits			$(254)
Investments (excluding funds for retiree health benefits)	$7,830	$6,525	$17,121
Pending activities (l)			(99)
Total fair value of plan net assets			$17,022

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

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

(c)U.S. Government Issued Debt includes agency and treasury securities.

(d)Corporate Bonds Debt consists of debt issued by various corporations.

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

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

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

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

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

(j)Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.

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

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

(m)In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy.

The fair values of the pension plan assets at December 31, 2019 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,652	$—	$3,652
International Equity (b)	3,354	—	3,354
U.S. Government Issued Debt (c)	—	1,496	1,496
Corporate Bonds Debt (d)	—	3,260	3,260
Structured Assets Debt (e)	—	173	173
Other Fixed Income Debt (f)	—	955	955
Cash and Cash Equivalents (g)	—	326	326
Total investments within the fair value hierarchy	$7,006	$6,210	$13,216
Investments measured at NAV per share (m)
Private Equity (h)			555
Real Estate (i)			1,806
Hedge Funds (j)			270
Total investments valued using NAV per share			$2,631
Funds for retiree health benefits (k)	(110)	(98)	(208)
Funds for retiree health benefits measured at NAV per share (k)(m)			(42)
Total funds for retiree health benefits			$(250)
Investments (excluding funds for retiree health benefits)	$6,896	$6,112	$15,597
Pending activities (l)			11
Total fair value of plan net assets			$15,608

(a) - (m) Reference is made to footnotes (a) through (m) in the above table of pension plan assets at December 31, 2020 by asset category.

The fair values of the plans' assets at December 31, 2020 by asset category as defined by the accounting rules for fair value measurements (see Note Q) are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Equity (a)	$—	$448	$448
Other Fixed Income Debt (b)	—	367	367
Cash and Cash Equivalents (c)	—	27	27
Total investments	$—	$842	$842
Funds for retiree health benefits (d)	116	97	213
Investments (including funds for retiree health benefits)	$116	$939	$1,055
Funds for retiree health benefits measured at net asset value (d)(e)			41
Pending activities (f)			19
Total fair value of plan net assets			$1,115

(a)Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index.

(b)Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index.

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

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

(e)In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy.

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

The fair values of the plans' assets at December 31, 2019 by asset category (see Note Q) are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Equity (a)	$—	$404	$404
Other Fixed Income Debt (b)	—	331	331
Cash and Cash Equivalents (c)	—	23	23
Total investments	$—	$758	$758
Funds for retiree health benefits (d)	110	98	208
Investments (including funds for retiree health benefits)	$110	$856	$966
Funds for retiree health benefits measured at net asset value (d)(e)			42
Pending activities (f)			18
Total fair value of plan net assets			$1,026

(a) - (f) Reference is made to footnotes (a) through (f) in the above table of other postretirement benefit plan assets at December 31, 2020 by asset category.

Schedule of Employer Contribution to Defined Savings Plan

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

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Con Edison	$52	$49	$45
CECONY	43	42	39

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Other Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2020

Retirement Benefits [Abstract]

Net Periodic Benefit Costs

The components of the Companies’ total periodic benefit costs for 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Service cost – including administrative expenses	$293	$250	$290	$274	$232	$272
Interest cost on projected benefit obligation	549	601	561	515	564	525
Expected return on plan assets	(1,034)	(988)	(1,033)	(980)	(936)	(979)
Recognition of net actuarial loss	699	518	688	661	492	651
Recognition of prior service credit	(16)	(17)	(17)	(19)	(19)	(19)
TOTAL PERIODIC BENEFIT COST	$491	$364	$489	$451	$333	$450
Cost capitalized	(130)	(108)	(127)	(123)	(102)	(119)
Reconciliation to rate level	(250)	(15)	(92)	(239)	(12)	(100)
Total expense recognized	$111	$241	$270	$89	$219	$231

The components of the Companies’ total periodic postretirement benefit costs for 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Service cost	$21	$18	$20	$16	$13	$14
Interest cost on accumulated other postretirement benefit obligation	37	44	42	31	36	34
Expected return on plan assets	(66)	(66)	(73)	(54)	(54)	(63)
Recognition of net actuarial loss/(gain)	37	(9)	8	36	(10)	3
Recognition of prior service credit	(3)	(2)	(6)	(2)	(2)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	$26	$(15)	$(9)	$27	$(17)	$(14)
Cost capitalized	(9)	(7)	(8)	(7)	(5)	(6)
Reconciliation to rate level	(17)	12	8	(25)	7	9
Total credit recognized	$—	$(10)	($9)	$(5)	$(15)	($11)

Schedule of Funded Status

The funded status at December 31, 2020, 2019 and 2018 was as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$16,792	$14,449	$15,536	$15,750	$13,542	$14,567
Service cost – excluding administrative expenses	288	245	286	269	228	267
Interest cost on projected benefit obligation	549	601	561	515	564	525
Net actuarial loss/(gain)	2,281	2,191	(1,219)	2,154	2,076	(1,159)
Plan amendments	—	15	—	—	—	—
Benefits paid	(945)	(709)	(715)	(867)	(660)	(658)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$18,965	$16,792	$14,449	$17,821	$15,750	$13,542
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$15,608	$13,450	$14,274	$14,790	$12,744	$13,519
Actual return on plan assets	1,927	2,556	(536)	1,830	2,425	(507)
Employer contributions	475	350	473	435	318	434
Benefits paid	(945)	(709)	(715)	(867)	(660)	(658)
Administrative expenses	(43)	(39)	(46)	(41)	(37)	(44)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$17,022	$15,608	$13,450	$16,147	$14,790	$12,744
FUNDED STATUS	$(1,943)	$(1,184)	$(999)	$(1,674)	$(960)	$(798)
Unrecognized net loss	$3,330	$2,604	$2,464	$3,145	$2,466	$2,338
Unrecognized prior service costs/(credits)	(156)	(173)	(205)	(183)	(202)	(222)
Accumulated benefit obligation	16,768	15,015	13,030	15,676	14,010	12,161

The funded status of the programs at December 31, 2020, 2019 and 2018 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$1,357	$1,114	$1,219	$1,154	$913	$985
Service cost	21	18	20	16	13	14
Interest cost on accumulated postretirement benefit obligation	37	44	42	31	36	34
Amendments	—	(14)	—	—	—	—
Net actuarial loss/(gain)	74	264	(70)	63	252	(32)
Benefits paid and administrative expenses, net of subsidies	(117)	(110)	(135)	(107)	(100)	(125)
Participant contributions	53	41	38	52	40	37
BENEFIT OBLIGATION AT END OF YEAR	$1,425	$1,357	$1,114	$1,209	$1,154	$913
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$1,026	$885	$1,039	$872	$759	$893
Actual return on plan assets	142	198	(66)	117	165	(54)
Employer contributions	7	7	6	4	6	6
Employer group waiver plan subsidies	20	23	34	19	22	32
Participant contributions	53	40	37	51	40	37
Benefits paid	(133)	(127)	(165)	(123)	(120)	(155)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$1,115	$1,026	$885	$940	$872	$759
FUNDED STATUS	$(310)	$(331)	$(229)	$(269)	$(282)	$(154)
Unrecognized net loss/(gain)	$115	$155	$14	$114	$149	$(2)
Unrecognized prior service costs	(16)	(19)	(8)	(1)	(3)	(5)

Schedule of Actuarial Assumptions

The actuarial assumptions were as follows: 

	2020		2019		2018
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate	2.55	%	3.35	%	4.25	%
Interest crediting rate for cash balance plan	3.00	%	3.30	%	4.00	%
Rate of compensation increase
CECONY	3.80	%	3.80	%	4.25	%
O&R	3.20	%	3.20	%	4.00	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	3.35	%	4.25	%	3.70	%
Interest crediting rate for cash balance plan	3.30	%	4.00	%	4.10	%
Expected return on plan assets	7.00	%	7.00	%	7.50	%
Rate of compensation increase
CECONY	3.80	%	4.25	%	4.25	%
O&R	3.20	%	4.00	%	4.00	%

The actuarial assumptions were as follows: 

	2020		2019		2018
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY	2.25	%	3.10	%	4.15	%
O&R	2.55	%	3.35	%	4.30	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate
CECONY	3.10	%	4.15	%	3.55	%
O&R	3.35	%	4.30	%	3.70	%
Expected Return on Plan Assets	6.80	%	6.80	%	7.50	%

Schedule of Change of Assumed Health Care Cost Trend Rate

Schedule of Expected Benefit Payments

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

(Millions of Dollars)	2021	2022	2023	2024	2025	2026-2030
Con Edison	$764	$776	$793	$807	$821	$4,295
CECONY	706	718	733	747	760	3,992

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

(Millions of Dollars)	2021	2022	2023	2024	2025	2026-2030
Con Edison	$84	$84	$84	$84	$84	$409
CECONY	76	75	75	75	75	358

Schedule of Plan Assets Allocations

The asset allocations for the pension plan at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2021	2020		2019		2018
Equity Securities	45% - 55%	51	%	51	%	51	%
Debt Securities	33% - 43%	38	%	38	%	39	%
Real Estate	10% - 14%	11	%	11	%	10	%
Total	100%	100	%	100	%	100	%

The asset allocations for CECONY’s other postretirement benefit plans at the end of 2020, 2019 and 2018, and the target allocation for 2021 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2021	2020		2019		2018
Equity Securities	42%-80%	54	%	54	%	52	%
Debt Securities	20%-58%	46	%	46	%	48	%
Total	100%	100	%	100	%	100	%

Schedule of Fair Value of Plan Assets

The fair values of the pension plan assets at December 31, 2020 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Investments within the fair value hierarchy
U.S. Equity (a)	$4,202	$—	$4,202
International Equity (b)	3,693	—	3,693
U.S. Government Issued Debt (c)	—	1,424	1,424
Corporate Bonds Debt (d)	—	3,535	3,535
Structured Assets Debt (e)	—	188	188
Other Fixed Income Debt (f)	—	1,067	1,067
Cash and Cash Equivalents (g)	51	408	459
Total investments within the fair value hierarchy	$7,946	$6,622	$14,568
Investments measured at NAV per share (m)
Private Equity (h)			635
Real Estate (i)			1,880
Hedge Funds (j)			292
Total investments valued using NAV per share			$2,807
Funds for retiree health benefits (k)	(116)	(97)	(213)
Funds for retiree health benefits measured at NAV per share (k)(m)			(41)
Total funds for retiree health benefits			$(254)
Investments (excluding funds for retiree health benefits)	$7,830	$6,525	$17,121
Pending activities (l)			(99)
Total fair value of plan net assets			$17,022

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

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

(c)U.S. Government Issued Debt includes agency and treasury securities.

(d)Corporate Bonds Debt consists of debt issued by various corporations.

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

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

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

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

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

(j)Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.

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

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

(m)In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy.

The fair values of the pension plan assets at December 31, 2019 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,652	$—	$3,652
International Equity (b)	3,354	—	3,354
U.S. Government Issued Debt (c)	—	1,496	1,496
Corporate Bonds Debt (d)	—	3,260	3,260
Structured Assets Debt (e)	—	173	173
Other Fixed Income Debt (f)	—	955	955
Cash and Cash Equivalents (g)	—	326	326
Total investments within the fair value hierarchy	$7,006	$6,210	$13,216
Investments measured at NAV per share (m)
Private Equity (h)			555
Real Estate (i)			1,806
Hedge Funds (j)			270
Total investments valued using NAV per share			$2,631
Funds for retiree health benefits (k)	(110)	(98)	(208)
Funds for retiree health benefits measured at NAV per share (k)(m)			(42)
Total funds for retiree health benefits			$(250)
Investments (excluding funds for retiree health benefits)	$6,896	$6,112	$15,597
Pending activities (l)			11
Total fair value of plan net assets			$15,608

(a) - (m) Reference is made to footnotes (a) through (m) in the above table of pension plan assets at December 31, 2020 by asset category.

The fair values of the plans' assets at December 31, 2020 by asset category as defined by the accounting rules for fair value measurements (see Note Q) are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Equity (a)	$—	$448	$448
Other Fixed Income Debt (b)	—	367	367
Cash and Cash Equivalents (c)	—	27	27
Total investments	$—	$842	$842
Funds for retiree health benefits (d)	116	97	213
Investments (including funds for retiree health benefits)	$116	$939	$1,055
Funds for retiree health benefits measured at net asset value (d)(e)			41
Pending activities (f)			19
Total fair value of plan net assets			$1,115

(a)Equity includes a passively managed commingled index fund benchmarked to the MSCI All Country World Index.

(b)Other Fixed Income Debt includes a passively managed commingled index fund benchmarked to the Bloomberg Barclays U.S. Long Credit Index and an active separately managed fund indexed to the Bloomberg Barclays U.S. Long Credit Index.

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

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

(e)In accordance with ASU 2015-07, Fair Value Measurements (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy.

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

The fair values of the plans' assets at December 31, 2019 by asset category (see Note Q) are as follows:

(Millions of Dollars)	Level 1	Level 2	Total
Equity (a)	$—	$404	$404
Other Fixed Income Debt (b)	—	331	331
Cash and Cash Equivalents (c)	—	23	23
Total investments	$—	$758	$758
Funds for retiree health benefits (d)	110	98	208
Investments (including funds for retiree health benefits)	$110	$856	$966
Funds for retiree health benefits measured at net asset value (d)(e)			42
Pending activities (f)			18
Total fair value of plan net assets			$1,026

(a) - (f) Reference is made to footnotes (a) through (f) in the above table of other postretirement benefit plan assets at December 31, 2020 by asset category.

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Environmental Matters (Tables)

12 Months Ended

Dec. 31, 2020

Environmental Remediation Obligations [Abstract]

Accrued Liabilities and Regulatory Assets

The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Accrued Liabilities:
Manufactured gas plant sites	$752	$640	$676	$561
Other Superfund Sites	105	94	104	93
Total	$857	$734	$780	$654
Regulatory assets	$865	$732	$791	$647

Environmental Remediation Costs

Environmental remediation costs incurred related to Superfund Sites at December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Remediation costs incurred	$33	$19	$32	$13

Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$72	$78	$68	$73
Regulatory assets/(liabilities) – workers’ compensation	$(3)	$3	$(3)	$3

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Material Contingencies (Tables)

12 Months Ended

Dec. 31, 2020

Commitments and Contingencies Disclosure [Abstract]

Summary of Total Guarantees

A summary, by type and term, of Con Edison’s total guarantees under these other agreements at December 31, 2020 is as follows:

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years	Total
	(Millions of Dollars)
Con Edison Transmission	$393	$177	$—	$570
Energy transactions	480	51	222	753
Renewable electric production projects	285	9	355	649
Other	70	—	—	70
Total	$1,228	$237	$577	$2,042

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Electricity Purchase Agreements (Tables)

12 Months Ended

Dec. 31, 2020

Regulated Operations [Abstract]

Summary of Estimated Capacity and Other Fixed Payments

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

(Millions of Dollars)	2021	2022	2023	2024	2025	All Years Thereafter
Con Edison	$141	$106	$68	$53	$54	$487
CECONY	138	106	68	53	54	487

Summary of Capacity, Energy and Other Fixed Payments

The company’s payments under the significant terms of the agreements for capacity, energy and other fixed payments in 2020, 2019 and 2018 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2020	2019	2018
Indian Point (a)	$—	$—	$6
Astoria Generating Company (b)	26	116	179
Brooklyn Navy Yard (c)	113	115	124
Cogen Technologies	—	—	9
Total	$139	$231	$318

(a) Contract term ended in 2018.

(b) Capacity purchase agreements with terms ending in 2020 and 2023.

(c) Contract for plant output, which started in 1996 and ends in 2036.

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Leases (Tables)

12 Months Ended

Dec. 31, 2020

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 twelve months ended December 31, 2020 and 2019 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Operating lease cost	$85	$83	$65	$64
Operating lease cash flows	$79	$75	$61	$60

Other information related to leases for Con Edison and CECONY at December 31, 2020 and 2019 was as follows:

	Con Edison		CECONY
	2020	2019	2020	2019
Weighted Average Remaining Lease Term:
Operating leases	19.1 years	19.8 years	13.0 years	14.0 years
Finance leases	7.3 years	12.2 years	4.0 years	2.4 years
Weighted Average Discount Rate:
Operating leases	4.3%	4.3%	3.6%	3.6%
Finance leases	1.8%	3.5%	1.3%	4.1%

Operating Leases, Future Minimum Lease Payments

Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending December 31,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2021	$79	$1	$62	$1
2022	77	1	58	1
2023	74	—	57	—
2024	75	—	57	—
2025	75	—	58	—
All years thereafter	938	1	451	—
Total future minimum lease payments	$1,318	$3	$743	$2
Less: imputed interest	(458)	—	(158)	—
Total	$860	$3	$585	$2
Reported as of December 31, 2020
Operating lease liabilities (current)	$96	$—	$73	$—
Operating lease liabilities (noncurrent)	764	—	512	—
Other current liabilities	—	1	—	1
Other noncurrent liabilities	—	2	—	1
Total	$860	$3	$585	$2

Finance Leases, Future Minimum Lease Payments

Future minimum lease payments under non-cancellable leases at December 31, 2020 were as follows:

(Millions of Dollars)	Con Edison		CECONY
Year Ending December 31,	Operating Leases	Finance Leases	Operating Leases	Finance Leases
2021	$79	$1	$62	$1
2022	77	1	58	1
2023	74	—	57	—
2024	75	—	57	—
2025	75	—	58	—
All years thereafter	938	1	451	—
Total future minimum lease payments	$1,318	$3	$743	$2
Less: imputed interest	(458)	—	(158)	—
Total	$860	$3	$585	$2
Reported as of December 31, 2020
Operating lease liabilities (current)	$96	$—	$73	$—
Operating lease liabilities (noncurrent)	764	—	512	—
Other current liabilities	—	1	—	1
Other noncurrent liabilities	—	2	—	1
Total	$860	$3	$585	$2

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Income Tax (Tables)

12 Months Ended

Dec. 31, 2020

Income Tax Disclosure [Abstract]

Schedule of Components of Income Tax

The components of income tax are as follows:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
State
Current	$7	$(12)	$(10)	$6	$22	$6
Deferred	50	96	107	97	68	82
Federal
Current	(2)	—	3	41	185	(34)
Deferred	42	219	310	73	63	275
Amortization of investment tax credits	(7)	(7)	(9)	(2)	(3)	(3)
Total income tax expense	$90	$296	$401	$215	$335	$326

Schedule of Differences on Deferred Tax Assets and Liabilities

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

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Deferred tax liabilities:
Property basis differences	$7,985	$7,699	$6,901	$6,640
Regulatory assets:
Unrecognized pension and other postretirement costs	910	712	861	674
Environmental remediation costs	243	205	222	181
Deferred storm costs	31	22	—	—
Other regulatory assets	536	376	508	355
Operating lease right-of-use asset	220	231	165	169
Equity investments	46	104	—	—
Total deferred tax liabilities	$9,971	$9,349	$8,657	$8,019
Deferred tax assets:
Accrued pension and other postretirement costs	$504	$291	$427	$222
Regulatory liabilities:
Future income tax	617	678	579	638
Other regulatory liabilities	656	702	570	622
Superfund and other environmental costs	241	206	219	183
Asset retirement obligations	178	135	143	102
Operating lease liabilities	211	231	165	170
Loss carryforwards	164	108	34	—
Tax credits carryforward	1,022	896	—	—
Valuation allowance	(22)	(31)	—	—
Other	59	47	127	103
Total deferred tax assets	3,630	3,263	2,264	2,040
Net deferred tax liabilities	$6,341	$6,086	$6,393	$5,979
Unamortized investment tax credits	134	141	18	21
Net deferred tax liabilities and unamortized investment tax credits	$6,475	$6,227	$6,411	$6,000

Schedule of Income Tax Reconciliation

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

	Con Edison						CECONY
(% of Pre-tax income)	2020		2019		2018		2020		2019		2018
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	4		4		4		5		5		5
Taxes attributable to noncontrolling interests	(1)		(1)		—		—		—		—
Cost of removal	2		1		1		1		1		1
Other plant-related items	(1)		(1)		(1)		(1)		(1)		(1)
TCJA deferred tax re-measurement	—		—		2		—		—		—
Amortization of excess deferred federal income taxes	(14)		(4)		(3)		(12)		(4)		(3)
Renewable energy credits	(3)		(2)		(1)		—		—		—
Research and development credits	—		(1)		—		—		(1)		(1)
Other	(1)		—		—		1		—		(1)
Effective tax rate	7	%	17	%	23	%	15	%	21	%	21	%

Summary of Unrecognized Tax Benefits

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

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Balance at January 1,	$13	$6	$12	$2	$4	$5
Additions based on tax positions related to the current year	—	1	2	—	1	2
Additions based on tax positions of prior years	1	10	1	1	—	1
Reductions for tax positions of prior years	—	(2)	(2)	—	(1)	(1)
Reductions from expiration of statute of limitations	—	—	(4)	—	—	—
Settlements	—	(2)	(3)	—	(2)	(3)
Balance at December 31,	$14	$13	$6	$3	$2	$4

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Revenue Recognition (Tables)

12 Months Ended

Dec. 31, 2020

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following table presents, for the years ended December 31, 2020 and 2019, revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source.

	2020				2019				2018
(Millions of Dollars)	Revenues from contracts with customers		Other revenues (a)	Total operating revenues	Revenues from contracts with customers		Other revenues (a)	Total operating revenues	Revenues from contracts with customers		Other revenues (a)	Total operating revenues
CECONY
Electric	$8,026		$77	$8,103	$7,913		$149	$8,062	$7,920		$51	$7,971
Gas	1,998		38	2,036	2,097		35	2,132	2,052		26	2,078
Steam	494		14	508	610		17	627	625		6	631
Total CECONY	$10,518		$129	$10,647	$10,620		$201	$10,821	$10,597		$83	$10,680
O&R
Electric	619		10	629	627		7	634	647		(5)	642
Gas	224		9	233	247		12	259	256		(7)	249
Total O&R	$843		$19	$862	$874		$19	$893	$903		$(12)	$891
Clean Energy Businesses
Renewables	609	(b)	—	609	575	(b)	—	575	329	(b)	—	329
Energy services	52		—	52	71		—	71	95		—	95
Other	—		75	75	—		211	211	—		339	339
Total Clean Energy Businesses	$661		$75	$736	$646		$211	$857	$424		$339	$763
Con Edison Transmission	4		—	4	4		—	4	4		—	4
Other (c)	—		(3)	(3)	—		(1)	(1)	—		(1)	(1)
Total Con Edison	$12,026		$220	$12,246	$12,144		$430	$12,574	$11,928		$409	$12,337

(a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans. For the Clean Energy Businesses, this includes revenue from wholesale services.

(b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $8 million, $14 million and $103 million for the years ended December 31, 2020, 2019 and 2018, respectively, of revenue related to engineering, procurement and construction services.

(c) Parent company and consolidation adjustments.

Change in Unbilled Contract and Unearned Revenues

	2020			2019			2018
(Millions of Dollars)	Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)
Beginning balance as of January 1,	$29	$17		$29	$20		$58	$87
Additions (c)	88	31		86	1		144	38
Subtractions (c)	106	7	(d)	86	4	(d)	173	105	(d)
Ending balance as of December 31,	$11	$41		$29	$17		$29	$20

(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, $7 million, $4 million and $50 million were included in the balances as of January 1, 2020, 2019, and 2018, respectively.

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Stock-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2020

Share-based Payment Arrangement [Abstract]

Summary of Stock-Based Compensation Expense

The following table summarizes stock-based compensation expense recognized by the Companies in the years ended December 31, 2020, 2019 and 2018:

	Con Edison			CECONY
(Millions of Dollars)	2020	2019	2018	2020	2019	2018
Performance-based restricted stock	$7	$36	$3	$6	$30	$3
Time-based restricted stock	1	2	2	1	2	1
Non-employee director deferred stock compensation	2	2	3	2	2	3
Stock purchase plan	7	7	6	7	6	6
Total	$17	$47	$14	$16	$40	$13
Income tax benefit	$5	$13	$4	$4	$11	$4

Assumptions Used to Calculate Fair Value of Awards

The assumptions used to calculate the fair value of the awards were as follows:

	2020	2019	2018
Risk-free interest rate (a)	0.10% - 0.13%	1.58% - 1.59%	2.48% -2.63%
Expected term (b)	3 years	3 years	3 years
Expected share price volatility (c)	30.16% - 40.95%	12.89% - 15.51%	14.76% - 17.71%

(a)The risk-free rate is based on the U.S. Treasury zero-coupon yield curve.

(b)The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur.

(c)Based on historical experience.

Summary of Changes in Status of Performance RSUs

A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2020 is as follows:

	Con Edison			CECONY
		Weighted Average Grant Date Fair Value (a)			Weighted Average Grant Date Fair Value (a)
	Units	TSR Portion (b)	Non-TSR Portion (c)	Units	TSR Portion (b)	Non-TSR Portion (c)
Non-vested at December 31, 2019	991,238	$68.15	$77.14	742,204	$68.06	$77.32
Granted	329,600	79.98	90.48	249,761	79.70	89.65
Vested	(326,496)	73.07	74.57	(245,269)	72.70	74.76
Forfeited	(92,818)	73.80	87.98	(60,225)	73.61	87.73
Non-vested at December 31, 2020	901,524	$70.11	$81.83	686,471	$70.15	$81.80

(a)The TSR and non-TSR Portions each account for 50 percent of the awards’ value.

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

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

Summary of Changes in Status of Time-Based Awards

A summary of changes in the status of time-based awards during the year ended December 31, 2020 is as follows:

	Con Edison		CECONY
	Units	Weighted Average Grant Date Fair Value	Units	Weighted Average Grant Date Fair Value
Non-vested at December 31, 2019	67,250	$80.36	63,100	$80.36
Granted	22,450	78.00	20,900	78.00
Vested	(20,750)	77.66	(19,650)	77.66
Forfeited	(1,512)	80.30	(1,512)	80.30
Non-vested at December 31, 2020	67,438	$80.40	62,838	$80.42

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Financial Information by Business Segment (Tables)

12 Months Ended

Dec. 31, 2020

Segment Reporting [Abstract]

Financial Data for Business Segments

The financial data for the business segments are as follows:

As of and for the Year Ended December 31, 2020 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$8,103	$18	$1,214	$1,731	$(134)	$535	$130	$35,673	$2,080
Gas	2,036	7	294	574	(25)	164	102	12,678	1,044
Steam	508	74	90	5	(12)	40	(14)	2,616	122
Consolidation adjustments	—	(99)	—	—	—	—	—	—	—
Total CECONY	$10,647	$—	$1,598	$2,310	($171)	$739	$218	$50,967	$3,246
O&R
Electric	$629	$—	$65	$99	$(10)	$26	$13	$2,097	$159
Gas	233	—	25	48	(4)	15	8	1,150	61
Other	—	—	—	—	—	—	—	—	—
Total O&R	$862	$—	$90	$147	$(14)	$41	$21	$3,247	$220
Clean Energy Businesses	$736	$—	$231	$215	$4	$196	$(43)	$6,848	$616
Con Edison Transmission	4	—	1	(8)	(215)	18	—	1,348	3
Other (b)	(3)	—	—	(10)	(5)	25	(3)	485	—
Total Con Edison	$12,246	$—	$1,920	$2,654	$(401)	$1,019	$193	$62,895	$4,085

As of and for the Year Ended December 31, 2019 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$8,062	$17	$1,053	$1,758	$(28)	$539	$239	$32,988	$1,851
Gas	2,132	7	231	528	(4)	147	99	11,090	1,078
Steam	627	70	89	62	(3)	42	4	2,479	91
Consolidation adjustments	—	(94)	—	—	—	—	—	—	—
Total CECONY	$10,821	$—	$1,373	$2,348	$(35)	$728	$342	$46,557	$3,020
O&R
Electric	$634	$—	$60	$98	$(7)	$27	$15	$2,130	$142
Gas	259	—	24	41	(4)	14	6	876	61
Other	—	—	—	—	—	—	—	—	—
Total O&R	$893	$—	$84	$139	$(11)	$41	$21	$3,006	$203
Clean Energy Businesses	$857	$—	$226	$202	$5	$186	$(58)	$6,528	$248
Con Edison Transmission	4	—	1	(6)	104	25	1	1,618	205
Other (b)	(1)	—	—	(7)	(12)	11	(6)	370	—
Total Con Edison	$12,574	$—	$1,684	$2,676	$51	$991	$300	$58,079	$3,676

As of and for the Year Ended December 31, 2018 (Millions of Dollars)	Operating revenues	Inter- segment revenues	Depreciation and amortization	Operating income	Other Income (deductions)	Interest charges	Income taxes on operating income (a)	Total assets	Capital expenditures
CECONY
Electric	$7,971	$16	$984	$1,799	$(110)	$519	$233	$31,012	$1,861
Gas	2,078	7	205	478	(23)	131	87	9,710	1,050
Steam	631	75	87	77	(10)	39	8	2,386	94
Consolidation adjustments	—	(98)	—	—	—	—	—	—	—
Total CECONY	$10,680	$—	$1,276	$2,354	$(143)	$689	$328	$43,108	$3,005
O&R
Electric	$642	$—	$56	$93	$(14)	$25	$14	$2,036	$138
Gas	249	—	21	39	(5)	14	7	856	67
Other	—	—	—	—	—	—	—	—	—
Total O&R	$891	$—	$77	$132	$(19)	$39	$21	$2,892	$205
Clean Energy Businesses	$763	$—	$85	$194	$33	$63	$19	$5,821	$1,791
Con Edison Transmission	4	—	1	(7)	91	20	(1)	1,425	248
Other (b)	(1)	—	(1)	(9)	(24)	8	39	674	—
Total Con Edison	$12,337	$—	$1,438	$2,664	$(62)	$819	$406	$53,920	$5,249

(a)For Con Edison, the income tax expense/(benefit) on non-operating income was $(103) million, $(4) million and $(5) million in 2020, 2019 and 2018, respectively. For CECONY, the income tax expense/(benefit) on non-operating income was $(3) million, $(7) million and $(2) million in 2020, 2019 and 2018, respectively.

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

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Derivative Instruments and Hedging Activities (Tables)

12 Months Ended

Dec. 31, 2020

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Offsetting of Assets

The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2020 and 2019 were:

(Millions of Dollars)	2020				2019
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	$44	$14	$58	(b)	$60	$(3)	$57	(b)
Noncurrent	22	35	57		19	(13)	6	(d)
Total fair value of derivative assets	$66	$49	$115		$79	$(16)	$63
Fair value of derivative liabilities
Current	$(225)	$(13)	$(238)	(c)	$(140)	$17	$(123)	(d)
Noncurrent	(207)	(33)	(240)	(c)	(122)	16	(106)	(d)
Total fair value of derivative liabilities	$(432)	$(46)	$(478)		$(262)	$33	$(229)
Net fair value derivative assets/(liabilities)	$(366)	$3	$(363)		$(183)	$17	$(166)
CECONY
Fair value of derivative assets
Current	$20	$(12)	$8	(b)	$39	$(6)	$33	(b)
Noncurrent	16	(8)	8		17	(12)	5
Total fair value of derivative assets	$36	$(20)	$16		$56	$(18)	$38
Fair value of derivative liabilities
Current	$(174)	$11	$(163)		$(100)	$19	$(81)
Noncurrent	(114)	9	(105)		(80)	16	(64)
Total fair value of derivative liabilities	$(288)	$20	$(268)		$(180)	$35	$(145)
Net fair value derivative assets/(liabilities)	$(252)	$—	$(252)		$(124)	$17	$(107)

 

(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 December 31, 2020 and 2019, margin deposits for Con Edison ($3 million and $9 million, respectively) and CECONY ($3 million and $8 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

(c)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 range from 2024-2041.

(d)Includes amounts for interest rate swaps of $1 million in current assets, $(7) million in current liabilities and $(34) million in noncurrent liabilities. At December 31, 2019, the Clean Energy Businesses had interest rate swaps with notional amounts of $919 million. The expiration dates of the swaps range from 2024-2041.

Offsetting of Liabilities

The fair values of the Companies’ derivatives, including the offsetting of assets and liabilities, on the consolidated balance sheet at December 31, 2020 and 2019 were:

(Millions of Dollars)	2020				2019
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	$44	$14	$58	(b)	$60	$(3)	$57	(b)
Noncurrent	22	35	57		19	(13)	6	(d)
Total fair value of derivative assets	$66	$49	$115		$79	$(16)	$63
Fair value of derivative liabilities
Current	$(225)	$(13)	$(238)	(c)	$(140)	$17	$(123)	(d)
Noncurrent	(207)	(33)	(240)	(c)	(122)	16	(106)	(d)
Total fair value of derivative liabilities	$(432)	$(46)	$(478)		$(262)	$33	$(229)
Net fair value derivative assets/(liabilities)	$(366)	$3	$(363)		$(183)	$17	$(166)
CECONY
Fair value of derivative assets
Current	$20	$(12)	$8	(b)	$39	$(6)	$33	(b)
Noncurrent	16	(8)	8		17	(12)	5
Total fair value of derivative assets	$36	$(20)	$16		$56	$(18)	$38
Fair value of derivative liabilities
Current	$(174)	$11	$(163)		$(100)	$19	$(81)
Noncurrent	(114)	9	(105)		(80)	16	(64)
Total fair value of derivative liabilities	$(288)	$20	$(268)		$(180)	$35	$(145)
Net fair value derivative assets/(liabilities)	$(252)	$—	$(252)		$(124)	$17	$(107)

 

(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 December 31, 2020 and 2019, margin deposits for Con Edison ($3 million and $9 million, respectively) and CECONY ($3 million and $8 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.

(c)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 range from 2024-2041.

(d)Includes amounts for interest rate swaps of $1 million in current assets, $(7) million in current liabilities and $(34) million in noncurrent liabilities. At December 31, 2019, the Clean Energy Businesses had interest rate swaps with notional amounts of $919 million. The expiration dates of the swaps range 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 years ended December 31, 2020 and 2019:

		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2020	2019	2020	2019
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(26)	$4	$(27)	$5
Noncurrent	Deferred derivative gains	—	(3)	—	(1)
Total deferred gains/(losses)		$(26)	$1	$(27)	$4
Current	Deferred derivative losses	$(63)	$(91)	$(64)	$(83)
Current	Recoverable energy costs	(201)	(142)	(177)	(124)
Noncurrent	Deferred derivative losses	(37)	(67)	(36)	(65)
Total deferred gains/(losses)		$(301)	$(300)	$(277)	$(272)
Net deferred gains/(losses)		$(327)	$(299)	$(304)	$(268)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Gas purchased for resale	$(2)	$(2)	$—	$—
	Non-utility revenue	7	25	—	—
	Other operations and maintenance expense	(3)	1	(3)	1
	Other interest expense	(65)	(36)	—	—
Total pre-tax gain/(loss) recognized in income		$(63)	$(12)	$(3)	$1

Hedged Volume of Derivative Transactions

The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at December 31, 2020:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	28,102,230	47,258	286,819,910	7,728,000
CECONY	26,193,800	35,400	267,380,000	7,728,000

 

(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 December 31, 2020:

(Millions of Dollars)	Con Edison (a)	CECONY (a)
Aggregate fair value – net liabilities	$293	$277
Collateral posted	212	200
Additional collateral (b) (downgrade one level from current ratings)	5	—
Additional collateral (b)(c) (downgrade to below investment grade from current ratings)	101	85

 

(a)Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $25 million at December 31, 2020. 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 December 31, 2020, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $51 million.

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Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2020

Fair Value Disclosures [Abstract]

Assets and Liabilities Measured at Fair Value on Recurring Basis

For information on the measurement of Con Edison's investment in MVP, which was measured at fair value on a non-recurring basis, see Note A. Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2020 and 2019 are summarized below.

	2020					2019
(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)	$19	$42	$4	$53	$118	$4	$61	$2	$4	$71
Interest rate swaps (a)(b)(c)(f)	—	—	—	—	—	—	1	—	—	1
Other (a)(b)(d)	431	126	—	—	557	353	125	—	—	478
Total assets	$450	$168	$4	$53	$675	$357	$187	$2	$4	$550
Derivative liabilities:
Commodity (a)(b)(c)	$7	$296	$23	$46	$372	$18	$174	$18	$(22)	$188
Interest rate swaps (a)(b)(c)(f)	—	106	—	—	106	—	41	—	—	41
Total liabilities	$7	$402	$23	$46	$478	$18	$215	$18	$(22)	$229
CECONY
Derivative assets:
Commodity (a)(b)(c)	$15	$20	$—	$(16)	$19	$3	$42	$1	$—	$46
Other (a)(b)(d)	411	120	—	—	531	333	119	—	—	452
Total assets	$426	$140	$—	$(16)	$550	$336	$161	$1	$—	$498
Derivative liabilities:
Commodity (a)(b)(c)	$3	$274	$10	$(19)	$268	$15	$147	$7	$(24)	$145

 

(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 $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. Con Edison and CECONY had $24 million and $22 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2019 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of December 31, 2017 to less than three years as of December 31, 2019.

(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 December 31, 2020 and 2019, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.

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

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

(f)See Note P.

Schedule of Commodity Derivatives

	Fair Value of Level 3 at December 31, 2020
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison — Commodity
Electricity	(20)	Discounted Cash Flow	Forward capacity prices (a)	$0.06-$6.26 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(2.65)-$7.69 per MWh
Total Con Edison — Commodity	$(19)
CECONY — Commodity
Electricity	$(11)	Discounted Cash Flow	Forward capacity prices (a)	$0.08-$6.26 per kW-month
Transmission Congestion Contracts	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.23-$1.13 per MWh
Total CECONY — Commodity	$(10)

 

(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 for the years ended December 31, 2020 and 2019 and classified as Level 3 in the fair value hierarchy:

 

	Con Edison		CECONY
(Millions of Dollars)	2020	2019	2020	2019
Beginning balance as of January 1,	$(16)	$(13)	$(6)	$(2)
Included in earnings	(10)	(5)	(5)	—
Included in regulatory assets and liabilities	(7)	18	(4)	17
Settlements	15	8	6	1
Transfer out of level 3	(1)	(24)	(1)	(22)
Ending balance as of December 31,	$(19)	$(16)	$(10)	$(6)

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Variable Interest Entities (Tables)

12 Months Ended

Dec. 31, 2020

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Business Acquisitions, by Acquisition

At December 31, 2020 and 2019, 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)
(Millions of Dollars)	2020	2019	2020	2019
Non-utility property, less accumulated depreciation (f)(g)	284	293	446	461
Other assets	39	40	176	128
Total assets (a)	$323	$333	$622	$589
Other liabilities	13	17	71	18
Total liabilities (b)	$13	$17	$71	$18

(a)The assets of the Tax Equity Projects 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 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 $82 million and $62 million at December 31, 2020 and 2019, 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 $134 million and $126 million at December 31, 2020 and 2019, respectively.

(f)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.

(g)Non-utility property is reduced by accumulated depreciation of $9 million for Great Valley Solar, $15 million for Copper Mountain - Mesquite Solar at December 31, 2019.

Summary of VIEs

The following table summarizes the VIEs into which the Clean Energy Businesses have entered as of December 31, 2020:

Project Name	Generating Capacity (a) (MW AC)	Power Purchase Agreement Term in Years	Year of Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (b)
Great Valley Solar (c)	200	15-20	2018	California	$228
Copper Mountain - Mesquite Solar (c)	344	20-25	2018	Nevada and Arizona	417

 

(a)Represents ownership interest in the project.

(b)Maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest. Con Edison did not provide any financial or other support during the year that was not previously contractually required.

(c)For the projects comprising Great Valley Solar and Copper Mountain Mesquite Solar, refer to (d) and (e) in the table above.

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Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2020

Related Party Transactions [Abstract]

Summary of Costs of Administrative and Other Services Provided and Received

The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2020, 2019 and 2018 were as follows:

	CECONY
(Millions of Dollars)	2020	2019	2018
Cost of services provided	$128	$121	$115
Cost of services received	66	64	73

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Acquisitions, Investments and Dispositions (Tables)

12 Months Ended

Dec. 31, 2020

Business Combinations [Abstract]

Pro Forma Supplemental Information

Con Edison's revenues and net income for the years ended December 31, 2018 and 2017 as reported and pro forma to account on a consolidated basis for the acquisition as if the acquisition had been completed on January 1, 2017 instead of December 13, 2018 are as follows:

	Years ended December 31,
(Millions of Dollars)	2018	2017
As Reported
Revenue	$12,337	$12,033
Net income	1,382	1,525
PRO FORMA SUPPLEMENTAL INFORMATION
If Acquired January 1, 2017 (a)(b)
Revenue	$12,655	$12,331
Net income	1,279	1,612

(a) Reflects the following material adjustments:

•included additional interest expense of $37 million and $38 million in 2018 and 2017, respectively, that would have been incurred if $825 million that was borrowed in December 2018 under a variable rate term loan agreement to fund a portion of the purchase price for the acquisition had instead been borrowed for such purpose on January 1, 2017 at a fixed rate of 4.64% per annum; and

•with respect to the Previously-Owned JV Interests: eliminated the $131 million purchase accounting gain (pre-tax) that Con Edison recognized upon the completion of the acquisition in 2018 and reflected the $131 million purchase accounting gain in 2017; recorded the corresponding increase to the book value of the related net utility plant and power purchase agreement intangible asset as of January 1, 2017 instead of December 13, 2018, and included the increased depreciation and amortization expense in 2018 and 2017; and eliminated $33 million and $32 million of other income that Con Edison had recorded in 2018 and 2017, respectively, under the equity method of accounting.

(b) Recalculating each investor’s claim on the investee’s assets under the contractual liquidation waterfall as if the acquisition had been completed on January 1, 2017 is impracticable. Accordingly, no HLBV adjustments were made.

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General (Details)	12 Months Ended
	Dec. 31, 2020 registrant subsidiary
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of registrants | registrant	2
Number of regulated subsidiaries | subsidiary	2

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Summary of Significant Accounting Policies and Other Matters - Adoption of New Standard (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	$ 78
Accounts receivable - customers
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	70
Recoveries	8
Write-offs	(54)
Reserve adjustments	124
Ending Balance	148
Other receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	4
Recoveries	0
Write-offs	(2)
Reserve adjustments	5
Ending Balance	7
CECONY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic	73
CECONY | Accounts receivable - customers
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	65
Recoveries	6
Write-offs	(50)
Reserve adjustments	117
Ending Balance	138
CECONY | Other receivables
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	3
Recoveries	0
Write-offs	(1)
Reserve adjustments	2
Ending Balance	$ 4

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Summary of Significant Accounting Policies and Other Matters - Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Revenue from External Customer [Line Items]
Excise taxes	$ 335	$ 323	$ 330
CECONY
Revenue from External Customer [Line Items]
Excise taxes	$ 323	$ 312	$ 318

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Summary of Significant Accounting Policies and Other Matters - Plant and Depreciation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Public Utility, Property, Plant and Equipment [Line Items]
Accumulated amortization	$ 228	$ 126
Annual aggregate depreciation allowance	1,694
Other deferred charges and noncurrent assets	54
Prepaid Expense	12
Depreciation expense, other deferred charges and noncurrent assets and prepayments	7
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	10
Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	86	93
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 17	$ 10
Non-Utility Plant | Maximum | Land And Conduit
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	10 years
Non-Utility Plant | Maximum | Wind Power Generating Assets
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	30 years
Non-Utility Plant | Maximum | Solar Powered Generating Assets
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	35 years
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
AFUDC rates (percent)	5.20%	5.10%	5.40%
Average depreciation rates (percent)	3.50%	3.20%	3.20%
Annual aggregate depreciation allowance	$ 1,604
Other deferred charges and noncurrent assets	51
Prepaid Expense	11
Depreciation expense, other deferred charges and noncurrent assets and prepayments	6
Accumulated depreciation, other deferred charges and noncurrent assets and prepayments	8
CECONY | Software Licenses
Public Utility, Property, Plant and Equipment [Line Items]
Gross asset	81	$ 88
Estimated aggregate annual amortization expense	7
Accumulated amortization	$ 17	$ 10
CECONY | Electric | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY | Electric | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	85 years
CECONY | Gas | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY | Gas | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	90 years
CECONY | Steam | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY | Steam | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	80 years
CECONY | General Plant | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
CECONY | General Plant | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	55 years
O&R
Public Utility, Property, Plant and Equipment [Line Items]
AFUDC rates (percent)	5.30%	5.30%	2.20%
Average depreciation rates (percent)	3.20%	3.00%	2.90%
O&R | Electric | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
O&R | Electric | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	75 years
O&R | General Plant | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
O&R | General Plant | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	50 years

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Summary of Significant Accounting Policies and Other Matters - Capitalized Cost of Utility Plant (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 3,880	$ 3,562
Held for future use	92	75
Construction work in progress	2,474	1,937
NET UTILITY PLANT	42,024	39,751
Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	572	591
Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	3,786	3,634
Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	21,481	20,676
General
Public Utility, Property, Plant and Equipment [Line Items]
General	52	43
Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	9,206	8,617
Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,854	1,813
General
Public Utility, Property, Plant and Equipment [Line Items]
General	2,507	2,365
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
General	3,585	3,271
Held for future use	84	67
Construction work in progress	2,320	1,812
NET UTILITY PLANT	39,552	37,412
CECONY | Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	572	591
CECONY | Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	3,496	3,380
CECONY | Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	20,366	19,602
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	52	43
CECONY | Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	8,522	7,961
CECONY | Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,854	1,813
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 2,286	$ 2,143

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Summary of Significant Accounting Policies and Other Matters - Long-Lived and Intangible Assets (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Finite-Lived Intangible Assets [Line Items]
Accumulated amortization	$ 228,000,000	$ 126,000,000
Amortization of intangible assets	102,000,000	99,000,000	$ 14,000,000
Amortization expense, 2020	102,000,000
Amortization expense, 2021	102,000,000
Amortization expense, 2022	102,000,000
Amortization expense, 2023	102,000,000
Amortization expense, 2024	102,000,000
Impairment charges	0	0	$ 2,000,000
Net non-utility plant	46,555,000,000	43,889,000,000
Intangible assets	1,460,000,000	1,557,000,000
Long-term debt	22,349,000,000	19,973,000,000
Other Intangible Assets
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	3,000,000
Accumulated amortization	8,000,000	7,000,000
Power Purchase Agreements
Finite-Lived Intangible Assets [Line Items]
Intangible assets, net	1,457,000,000	1,554,000,000
Accumulated amortization	$ 220,000,000	$ 119,000,000

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Summary of Significant Accounting Policies and Other Matters - Recoverable Energy Costs (Details)	12 Months Ended
	Dec. 31, 2020
Minimum
Public Utilities, General Disclosures [Line Items]
Recovery or refund of energy costs, deferral period	1 month
Maximum
Public Utilities, General Disclosures [Line Items]
Recovery or refund of energy costs, deferral period	2 months

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Summary of Significant Accounting Policies and Other Matters - Investments (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($) mi	Dec. 30, 2020 USD ($)	Dec. 31, 2019 USD ($)	Jan. 31, 2016
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	$ 465		$ 397
Deferred income plan assets	92		81
Other	3		2
Total investments	$ 1,816		2,065
Stagecoach
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage	50.00%
Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 530		530
Mountain Valley Pipeline | Minimum
Schedule of Equity Method Investments [Line Items]
Aggregate project cost	5,800
Mountain Valley Pipeline | Maximum
Schedule of Equity Method Investments [Line Items]
Aggregate project cost	$ 6,000
Mountain Valley Pipeline | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Expected ownership percentage	8.80%
CET | Stagecoach
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 845		924
CET | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	342		602
CET | New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	69		59
CECONY
Schedule of Equity Method Investments [Line Items]
Supplemental retirement income plan assets	439		371
Deferred income plan assets	92		81
Other	10		9
Total investments	541		461
CECONY | CET | Stagecoach
Schedule of Equity Method Investments [Line Items]
Equity method investments	0		0
CECONY | CET | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	0		0
CECONY | CET | New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	0		0
CET Gas | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 530		$ 530
Equity method investment, ownership percentage	11.30%
Carrying value of investment	$ 342	$ 662
Number of miles in pipeline construction | mi	77
Long -term firm transportation contract period	20 years
Cash flows discount rate	8.30%
Impairment loss	$ 320
Expected reduction in equity interest	8.80%
Impairment loss, after tax	$ 223
CET Gas | Mountain Valley Pipeline | Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage				12.50%

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Summary of Significant Accounting Policies and Other Matters - Pension and Other Postretirement Benefits (Details)	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Investment gains and losses recognized, time period (years)	15 years
Other actuarial gains and losses recognized, time period (years)	10 years
Difference between fair value and expected market related value of plan assets (percent)	20.00%

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Summary of Significant Accounting Policies and Other Matters - Research and Development Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Research and Development Expenses [Line Items]
Research and development costs	$ 24	$ 24	$ 24
CECONY
Research and Development Expenses [Line Items]
Research and development costs	$ 23	$ 23	$ 23

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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	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Net income	$ 1,101	$ 1,343	$ 1,382	$ 1,525
Weighted average common shares outstanding – basic (in shares)	334.8	328.5	311.7
Add: Incremental shares attributable to effect of potentially dilutive securities (in shares)	0.9	1.0	1.2
Adjusted weighted average common shares outstanding – diluted (in shares)	335.7	329.5	312.9
Net income per common share — basic (in dollars per share)	$ 3.29	$ 4.09	$ 4.43
Net income per common share — diluted (in dollars per share)	$ 3.28	$ 4.08	$ 4.42

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Summary of Significant Accounting Policies and Other Matters - Changes in Accumulated Other Comprehensive Income/(Loss) by Component (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	$ 18,213	$ 16,839	$ 15,425
BALANCE AS OF BEGINNING OF PERIOD	18,022
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
BALANCE AS OF END OF PERIOD	18,847	18,022
BALANCE AS OF END OF PERIOD	19,065	18,213	16,839
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(19)	(16)	(26)
BALANCE AS OF END OF PERIOD	(25)	(19)	(16)
Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	(11)	(10)	4
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	5	7	6
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
OCI before reclassifications, tax	4	(6)	3
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(2)	(2)	(2)
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(19)	(16)	(26)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(6)	(3)	10
BALANCE AS OF END OF PERIOD	(25)	(19)	(16)
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	14,147	12,910	12,439
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	1
BALANCE AS OF END OF PERIOD	14,849	14,147	12,910
CECONY | Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(6)	(5)	(6)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	1
BALANCE AS OF END OF PERIOD	(7)	(6)	(5)
CECONY | Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	(3)	(3)	0
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	2	2	1
TOTAL OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES	(1)	(1)	$ 1
OCI before reclassifications, tax	$ 1	$ (1)

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Summary of Significant Accounting Policies and Other Matters - Reconciliation of Cash, Temporary Investments and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	$ 1,272	$ 981
Restricted cash	164	236
Total cash, temporary cash investments and restricted cash	1,436	1,217	$ 1,006	$ 844
Cash Collateral Held For Project Finance Agreements | Clean Energy Businesses
Cash and Cash Equivalents [Line Items]
Restricted cash	164	236
CECONY
Cash and Cash Equivalents [Line Items]
Cash and temporary cash investments	1,067	933
Restricted cash	0	0
Total cash, temporary cash investments and restricted cash	$ 1,067	$ 933	$ 818	$ 730

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Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Electric) (Details) - USD ($)	1 Months Ended	12 Months Ended					36 Months Ended
	Dec. 31, 2016	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2022	Dec. 31, 2019	Dec. 31, 2016	Dec. 31, 2023
Public Utilities, General Disclosures [Line Items]
Revenues		$ 12,246,000,000	$ 12,574,000,000	$ 12,337,000,000	$ 12,033,000,000
Deferred revenues		41,000,000	17,000,000	20,000,000	87,000,000			$ 17,000,000
Deferred revenues		$ (599,000,000)	(599,000,000)					(599,000,000)
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
CECONY
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 46,000,000
Revenues		10,647,000,000	10,821,000,000	10,680,000,000
Deferred revenues		(523,000,000)	(477,000,000)					(477,000,000)
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues								75,000,000
Actual earnings adjustment mechanism incentives		34,000,000	43,000,000	25,000,000	13,000,000
Other earnings incentives		5,000,000	5,000,000	5,000,000
Deferred revenues		242,000,000	169,000,000	(6,000,000)	45,000,000			169,000,000
Negative revenue adjustments		5,000,000	15,000,000	0	0
Cost reconciliation, deferred net regulatory liabilities		288,000,000	10,000,000	189,000,000	35,000,000			10,000,000
Deferred regulatory asset (liability)		4,100,000	(11,800,000)	(400,000)	400,000			$ (11,800,000)
Earnings sharing, threshold limit		$ 0	0	0	$ 0
Earnings sharing, positive adjustment						$ 5,700,000
Common Equity Ratio, Percentage								4800.00%
Increase in gas base rate due to expiration of temporary credit under the prior rate plan	$ 48,000,000
Recovery or refund of energy costs, deferral period								10 years
Deferrals for property taxes limitation from rates (percent)									90.00%
Recovery deferral (percent)		80.00%
Maximum deferral (percent)		30.00%
CECONY | Electric | NYSPSC
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 199,000,000
CECONY | Electric | Service Termination
Public Utilities, General Disclosures [Line Items]
Revenues			$ 7,000,000	$ 3,000,000
CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Retention of annual transmission congestion revenues							$ 75,000,000
Weighted average cost of capital (after-tax) (percent)							661.00%
Authorized return on common equity (percent)							880.00%
Earnings sharing (percent)										9.30%
Common Equity Ratio, Percentage							4800.00%
Maximum deferral (percent)										15.00%
Income tax benefit to be credited to customers resulting from TCJA							$ 377,000,000
CECONY | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 195,000,000
Utilities operating expense, depreciation and amortization								$ 84,000,000
Potential earnings adjustment mechanism incentives								28,000,000
Average rate base								$ 18,902,000,000
Weighted average cost of capital (after-tax) (percent)								6.82%
Authorized return on common equity (percent)								900.00%
Actual return on common equity (percent)								9.30%
Earnings sharing (percent)		9.50%
Cost of long-term debt rate		4.93%
Recovery of energy efficiency and savings program costs								$ 20,500,000
Deferral, annual maximum (not more than) (percent)									10.00%
CECONY | Electric | Year 1 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								21,689,000,000
CECONY | Electric | Year 1 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								126,000,000
CECONY | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								376,000,000
CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 113,000,000
Utilities operating expense, depreciation and amortization							267,000,000
Potential earnings adjustment mechanism incentives							69,000,000
Potential penalties (annually)							450,000,000
Average rate base							$ 21,660,000,000
Actual return on common equity (percent)							8.50%
Cost of long-term debt rate										463.00%
Amount of cost recovery							$ 206,000,000
CECONY | Electric | Year 1 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							24,491,000,000
CECONY | Electric | Year 1 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							572,000,000
CECONY | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 155,000,000
Utilities operating expense, depreciation and amortization								83,000,000
Potential earnings adjustment mechanism incentives								47,000,000
Average rate base								$ 19,530,000,000
Weighted average cost of capital (after-tax) (percent)								6.80%
Actual return on common equity (percent)								9.36%
Cost of long-term debt rate		4.88%
Recovery of energy efficiency and savings program costs								$ 49,000,000
Deferral, annual maximum (not more than) (percent)									7.50%
CECONY | Electric | Year 2 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								22,338,000,000
CECONY | Electric | Year 2 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								257,000,000
CECONY | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								341,000,000
CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 370,000,000
Utilities operating expense, depreciation and amortization							269,000,000
Potential earnings adjustment mechanism incentives							74,000,000
Potential penalties (annually)							461,000,000
Average rate base							22,783,000,000
Amount of cost recovery							245,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							25,092,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							740,000,000
CECONY | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 155,000,000
Utilities operating expense, depreciation and amortization								69,000,000
Potential earnings adjustment mechanism incentives								64,000,000
Average rate base								$ 20,277,000,000
Weighted average cost of capital (after-tax) (percent)								6.73%
Actual return on common equity (percent)								8.82%
Cost of long-term debt rate		4.74%
Recovery of energy efficiency and savings program costs								$ 107,500,000
Deferral, annual maximum (not more than) (percent)									5.00%
CECONY | Electric | Year 3 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								23,002,000,000
CECONY | Electric | Year 3 | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations								415,000,000
CECONY | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								$ 352,000,000
CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes										$ 326,000,000
Utilities operating expense, depreciation and amortization							272,000,000
Potential earnings adjustment mechanism incentives							79,000,000
Potential penalties (annually)							476,000,000
Average rate base							23,926,000,000
Amount of cost recovery							251,000,000
CECONY | Electric | Year 3 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							25,708,000,000
CECONY | Electric | Year 3 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							806,000,000
Annually | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							126,000,000
Annually | CECONY | Electric | Scenario, Forecast | Deferred Project Costs
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization							48,000,000
Over Five Years | CECONY | Electric | Scenario, Forecast | Deferred Project Costs
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization							238,000,000
Over Three Years | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA							377,000,000
Protected Portion | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							1,663,000,000
Protected Portion | CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							49,000,000
Protected Portion | CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							50,000,000
Protected Portion | CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							53,000,000
Unprotected Portion | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							$ 784,000,000
TCJA of 2017 regulatory liabilities, income tax benefit, amortization period							5 years
Unprotected Portion | Annually | CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA							$ 157,000,000

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Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Gas) (Details) - USD ($)	1 Months Ended	12 Months Ended				36 Months Ended
	Dec. 31, 2016	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2022	Dec. 31, 2019	Dec. 31, 2023
Public Utilities, General Disclosures [Line Items]
Revenues		$ 12,246,000,000	$ 12,574,000,000	$ 12,337,000,000	$ 12,033,000,000
Deferred revenues		41,000,000	17,000,000	20,000,000	87,000,000		$ 17,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Revenues		10,647,000,000	10,821,000,000	10,680,000,000
CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve							15.00%
Other earnings incentives		3,000,000	7,000,000	6,000,000	7,000,000
Deferred revenues		27,000,000	10,000,000	12,000,000	3,000,000		$ 10,000,000
Negative revenue adjustments		0	0	4,000,000	5,000,000
Cost reconciliation, deferred net regulatory liabilities		91,000,000	18,000,000	44,000,000	2,000,000		18,000,000
Deferred regulatory asset (liability)		$ (24,700,000)	(1,700,000)	(2,200,000)	(2,200,000)		$ (1,700,000)
Earnings sharing (percent)		9.50%
Earnings sharing, threshold limit		$ 0	0	0	$ 0
Common Equity Ratio, Percentage							4800.00%
Increase in gas base rate due to expiration of temporary credit under the prior rate plan	$ 41,000,000
CECONY | Gas | Maximum
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained			65,000,000				$ 65,000,000
CECONY | Gas | Gas Leak Backlog, Leak Prone Pipe and Service Terminations
Public Utilities, General Disclosures [Line Items]
Revenues		$ 13,000,000	$ 9,000,000	$ 5,000,000
CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve						15.00%
Earnings sharing (percent)								9.30%
Common Equity Ratio, Percentage						4800.00%
Income tax benefit to be credited to customers resulting from TCJA						$ 63,000,000
CECONY | Gas | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained						65,000,000
CECONY | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes							(5,000,000)
Utilities operating expense, depreciation and amortization							39,000,000
Potential incentives if performance targets are met							7,000,000
Potential penalties (annually)							68,000,000
Average rate base							$ 4,841,000,000
Weighted average cost of capital (after-tax) (percent)							6.82%
Authorized return on common equity (percent)							900.00%
Actual return on common equity (percent)							9.22%
Cost of long-term debt rate		4.93%
CECONY | Gas | Year 1 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 5,844,000,000
CECONY | Gas | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							27,000,000
CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						84,000,000
Utilities operating expense, depreciation and amortization						45,000,000
Potential incentives if performance targets are met						20,000,000
Potential penalties (annually)						81,000,000
Average rate base						$ 7,171,000,000
Weighted average cost of capital (after-tax) (percent)						661.00%
Authorized return on common equity (percent)						880.00%
Actual return on common equity (percent)						8.40%
Cost of long-term debt rate								463.00%
CECONY | Gas | Year 1 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 8,108,000,000
CECONY | Gas | Year 1 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						142,000,000
CECONY | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes							92,000,000
Utilities operating expense, depreciation and amortization							37,000,000
Potential incentives if performance targets are met							8,000,000
Potential penalties (annually)							63,000,000
Average rate base							$ 5,395,000,000
Weighted average cost of capital (after-tax) (percent)							6.80%
Actual return on common equity (percent)							9.04%
Cost of long-term debt rate		4.88%
CECONY | Gas | Year 2 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 6,512,000,000
CECONY | Gas | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							57,000,000
CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						122,000,000
Utilities operating expense, depreciation and amortization						43,000,000
Potential incentives if performance targets are met						22,000,000
Potential penalties (annually)						88,000,000
Average rate base						7,911,000,000
CECONY | Gas | Year 2 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						8,808,000,000
CECONY | Gas | Year 2 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						183,000,000
CECONY | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes							90,000,000
Utilities operating expense, depreciation and amortization							36,000,000
Potential incentives if performance targets are met							8,000,000
Potential penalties (annually)							70,000,000
Average rate base							$ 6,005,000,000
Weighted average cost of capital (after-tax) (percent)							6.73%
Actual return on common equity (percent)							8.72%
Cost of long-term debt rate		4.74%
CECONY | Gas | Year 3 | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 7,177,000,000
CECONY | Gas | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 100,000,000
CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						167,000,000
Utilities operating expense, depreciation and amortization						10,000,000
Potential incentives if performance targets are met						25,000,000
Potential penalties (annually)						96,000,000
Average rate base						8,622,000,000
CECONY | Gas | Year 3 | Scenario, Forecast | Gas average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						9,510,000,000
CECONY | Gas | Year 3 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						211,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
NYSPSC | Maximum
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
Annually | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA						32,000,000
Over Ten Years | CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount						47,000,000
Amount of cost recovery						30,000,000
Over Ten Years | CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount						176,000,000
Amount of cost recovery						37,000,000
Over Ten Years | CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount						170,000,000
Amount of cost recovery						40,000,000
Over Two Years | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA						63,000,000
Protected Portion | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						725,000,000
Protected Portion | CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						14,000,000
Protected Portion | CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						14,000,000
Protected Portion | CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						12,000,000
Unprotected Portion | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						107,000,000
Unprotected Portion | Annually | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						21,000,000
Unprotected Portion | Over Five Years | CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA						$ 107,000,000

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Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Steam) (Details) - CECONY - Steam - USD ($)	12 Months Ended						36 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2016	Dec. 31, 2014
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization							$ 37,000,000
Regulatory liabilities, amortization period							3 years
Negative revenue adjustments	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Cost reconciliation, deferred net regulatory liabilities				$ 14,000,000	8,000,000		$ 8,000,000	$ 42,000,000
Cost reconciliation, deferred net regulatory assets	35,000,000	8,000,000	1,000,000			17,000,000
Increase (decrease) in regulatory liabilities	0	0	0			(100,000)
Authorized return on common equity (percent)							930.00%
Earnings sharing (percent)				9.90%
Earnings sharing, threshold limit	$ 5,000,000	16,500,000	8,500,000	$ 7,800,000	$ 11,500,000	$ 0
Earnings sharing, positive adjustment		$ 2,300,000	$ 1,100,000	4,000,000
Common Equity Ratio, Percentage							4800.00%
Other regulatory liabilities				$ 8,000,000
Difference in property taxes (percent)							90.00%
Deferral, annual maximum (not more than) (percent)							10.00%
Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes							$ (22,400,000)
Average rate base							$ 1,511,000,000
Weighted average cost of capital (after-tax) (percent)							7.10%
Actual return on common equity (percent)							9.82%
Cost of long-term debt rate				5.17%
Year 1 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 1,752,000,000
Year 1 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							6,000,000
Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							1,000,000
Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes							19,800,000
Average rate base							$ 1,547,000,000
Weighted average cost of capital (after-tax) (percent)							7.13%
Actual return on common equity (percent)							10.88%
Cost of long-term debt rate				5.23%
Year 2 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 1,732,000,000
Year 2 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							11,000,000
Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							1,000,000
Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes							20,300,000
Average rate base							$ 1,604,000,000
Weighted average cost of capital (after-tax) (percent)							7.21%
Actual return on common equity (percent)							10.54%
Cost of long-term debt rate				5.39%
Year 3 | Production
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							$ 1,720,000,000
Year 3 | Distribution
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							25,000,000
Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							1,000,000
Year 4
Public Utilities, General Disclosures [Line Items]
Base rate changes							$ 0
Actual return on common equity (percent)							9.51%
Year 5
Public Utilities, General Disclosures [Line Items]
Base rate changes							$ 0
Actual return on common equity (percent)							11.73%
Year 6
Public Utilities, General Disclosures [Line Items]
Base rate changes							$ 0
Actual return on common equity (percent)							10.45%
Year 7
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)							7.91%

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Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Electric) (Details) - USD ($)	1 Months Ended	12 Months Ended						24 Months Ended	36 Months Ended
	Jan. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Oct. 31, 2017	Dec. 31, 2021	Oct. 31, 2018	Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Deferred revenues		$ 41,000,000	$ 17,000,000	$ 20,000,000	$ 87,000,000
Deferred revenues		$ 599,000,000	599,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
O&R
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 3,000,000
O&R | Electric
Public Utilities, General Disclosures [Line Items]
Deferred revenues						$ 6,300,000
Deferred revenues		6,000,000	100,000	500,000	11,200,000
Negative revenue adjustments			0	0	0	1,250,000
Deferral of net increase (decrease) to regulatory assets		30,300,000	4,300,000	5,000,000	3,200,000	7,400,000	$ 300,000
Net utility plant reconciliations			1,400,000	(1,900,000)	(1,900,000)	2,200,000
Authorized return on common equity (percent)								900.00%
Earnings sharing (percent)								9.60%
Earnings sharing, threshold limit				300,000	6,100,000
Common Equity Ratio, Percentage								4800.00%
Deferred storm and property reserve deficiency, noncurrent								$ 59,300,000
Deferred storm and property reserve deficiency, recovery period								5 years
Deferred storm and property reserve deficiency not recovered								$ 1,000,000
Deferred Regulatory Asset (Liability)		400,000
O&R | Electric | NYSPSC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Common Equity Ratio, Percentage	50.00%
Requested rate increase (decrease), amount	$ 24,500,000
Return on common equity (percent)	9.50%
O&R | Electric | Property Tax and Interest Rate Reconciliations
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable								4,000,000
O&R | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes								9,300,000
Amortization to income of net regulatory assets								(8,500,000)
Net utility plant reconciliations								928,000,000
Average rate base								$ 763,000,000
Weighted average cost of capital (after-tax) (percent)								7.10%
Actual return on common equity (percent)								10.80%
Cost of long-term debt (percent)								5.42%
Deferred storm and property reserve deficiency, noncurrent								$ 11,850,000
Rate exclusion amount with balance below regulatory threshold								1,000,000
O&R | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								4,000,000
O&R | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes								8,800,000
Amortization to income of net regulatory assets								(9,400,000)
Net utility plant reconciliations								970,000,000
Average rate base								$ 805,000,000
Weighted average cost of capital (after-tax) (percent)								7.06%
Actual return on common equity (percent)								9.70%
Cost of long-term debt (percent)								5.35%
Rate exclusion amount with balance below regulatory threshold								$ 9,000,000
O&R | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								4,000,000
O&R | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes								0
Amortization to income of net regulatory assets								0
Average rate base								$ 805,000,000
Weighted average cost of capital (after-tax) (percent)								7.06%
Actual return on common equity (percent)								7.20%
Cost of long-term debt (percent)								5.35%
O&R | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								$ 4,000,000
O&R | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)									900.00%
Earnings sharing (percent)											9.60%
Common Equity Ratio, Percentage									4800.00%
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									$ 13,400,000
Amortization to income of net regulatory assets									(1,500,000)
Potential earnings adjustment mechanism incentives									3,600,000
Potential incentive if target is met, related to service terminations									500,000
Average rate base									$ 878,000,000
Weighted average cost of capital (after-tax) (percent)									6.97%
Actual return on common equity (percent)									9.60%
Cost of long-term debt (percent)									5.17%
Requested rate increase (decrease), amount									$ 8,600,000
Deferral, annual maximum (not more than) (percent)									10.00%
O&R | Electric | Scenario, Forecast | Year 1 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,008,000,000
O&R | Electric | Scenario, Forecast | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									48,000,000
O&R | Electric | Scenario, Forecast | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									4,400,000
O&R | Electric | Scenario, Forecast | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes									8,000,000.0
Amortization to income of net regulatory assets									(1,500,000)
Potential earnings adjustment mechanism incentives									4,000,000.0
Potential incentive if target is met, related to service terminations									500,000
Average rate base									$ 906,000,000
Weighted average cost of capital (after-tax) (percent)									6.96%
Actual return on common equity (percent)									8.76%
Cost of long-term debt (percent)									5.14%
Requested rate increase (decrease), amount									$ 12,100,000
Deferral, annual maximum (not more than) (percent)									7.50%
O&R | Electric | Scenario, Forecast | Year 2 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,032,000,000
O&R | Electric | Scenario, Forecast | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									58,000,000
O&R | Electric | Scenario, Forecast | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									4,400,000
O&R | Electric | Scenario, Forecast | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes									5,800,000
Amortization to income of net regulatory assets									(1,500,000)
Potential earnings adjustment mechanism incentives									4,200,000
Potential incentive if target is met, related to service terminations									500,000
Average rate base									$ 948,000,000
Weighted average cost of capital (after-tax) (percent)									6.96%
Cost of long-term debt (percent)									5.14%
Requested rate increase (decrease), amount									$ 12,200,000
Deferral, annual maximum (not more than) (percent)									5.00%
O&R | Electric | Scenario, Forecast | Year 3 | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									$ 1,083,000,000
O&R | Electric | Scenario, Forecast | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									61,000,000
O&R | Electric | Scenario, Forecast | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									4,500,000
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Deferred revenues			6,300,000	1,700,000	6,200,000
Deferred revenues		500,000	800,000			800,000
Negative revenue adjustments		200,000	100,000	0	0	$ 0
Authorized return on common equity (percent)										9.00%
Earnings sharing (percent)										9.60%
Earnings sharing, threshold limit				$ 200,000	$ 4,000,000
Common Equity Ratio, Percentage										4800.00%
Deferred Regulatory Asset (Liability)			400,000
O&R | Gas | NYSPSC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Common Equity Ratio, Percentage	50.00%
Requested rate increase (decrease), amount	$ 9,800,000
Return on common equity (percent)	9.50%
O&R | Gas | Property Tax and Interest Rate Reconciliations
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable										$ 14,000,000
O&R | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes										16,400,000
Amortization to income of net regulatory assets										(1,700,000)
Net utility plant reconciliations										492,000,000
Average rate base										$ 366,000,000
Weighted average cost of capital (after-tax) (percent)										7.10%
Actual return on common equity (percent)										11.20%
Cost of long-term debt (percent)										5.42%
Rate exclusion amount with balance below regulatory threshold										$ 500,000
O&R | Gas | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)										3,700,000
O&R | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes										16,400,000
Amortization to income of net regulatory assets										(2,100,000)
Net utility plant reconciliations										518,000,000
Average rate base										$ 391,000,000
Weighted average cost of capital (after-tax) (percent)										7.06%
Actual return on common equity (percent)										9.70%
Cost of long-term debt (percent)										5.35%
Rate exclusion amount with balance below regulatory threshold										$ 4,200,000
O&R | Gas | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)										4,700,000
O&R | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes										5,800,000
Amortization to income of net regulatory assets										(2,500,000)
Net utility plant reconciliations										546,000,000
Average rate base										$ 417,000,000
Weighted average cost of capital (after-tax) (percent)										7.06%
Actual return on common equity (percent)										8.10%
Cost of long-term debt (percent)										5.35%
Rate exclusion amount with balance below regulatory threshold										$ 7,200,000
O&R | Gas | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)										$ 4,900,000
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Potential earnings adjustment mechanism incentives									$ 300,000
Authorized return on common equity (percent)									9.00%
Earnings sharing (percent)											9.60%
Common Equity Ratio, Percentage									4800.00%
O&R | Gas | Scenario, Forecast | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes									$ (7,500,000)
Amortization to income of net regulatory assets									(1,800,000)
Potential earnings adjustment mechanism incentives									1,200,000
Net utility plant reconciliations									593,000,000
Average rate base									$ 454,000,000
Weighted average cost of capital (after-tax) (percent)									6.97%
Actual return on common equity (percent)									8.90%
Cost of long-term debt (percent)									5.17%
Requested rate increase (decrease), amount									$ (5,900,000)
O&R | Gas | Scenario, Forecast | Year 1 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									20,000,000
O&R | Gas | Scenario, Forecast | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									5,500,000
O&R | Gas | Scenario, Forecast | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes									3,600,000
Amortization to income of net regulatory assets									(1,800,000)
Potential earnings adjustment mechanism incentives									1,300,000
Net utility plant reconciliations									611,000,000
Average rate base									$ 476,000,000
Weighted average cost of capital (after-tax) (percent)									6.96%
Actual return on common equity (percent)									9.58%
Cost of long-term debt (percent)									5.14%
Requested rate increase (decrease), amount									$ 1,000,000.0
O&R | Gas | Scenario, Forecast | Year 2 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									24,000,000
O&R | Gas | Scenario, Forecast | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									5,700,000
O&R | Gas | Scenario, Forecast | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes									700,000
Amortization to income of net regulatory assets									(1,800,000)
Potential earnings adjustment mechanism incentives									1,300,000
Net utility plant reconciliations									632,000,000
Average rate base									$ 498,000,000
Weighted average cost of capital (after-tax) (percent)									6.96%
Cost of long-term debt (percent)									5.14%
Requested rate increase (decrease), amount									$ 1,000,000.0
O&R | Gas | Scenario, Forecast | Year 3 | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations									25,000,000
O&R | Gas | Scenario, Forecast | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)									$ 6,000,000.0
Energy Efficiency | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		2,600,000
Energy Efficiency | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		300,000
Service Termination | O&R | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		500,000	200,000
Service Termination | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 500,000	$ 700,000

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Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Gas) (Details) - USD ($)	1 Months Ended	12 Months Ended					36 Months Ended
	Jan. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2021	Oct. 31, 2018	Dec. 31, 2022	Dec. 31, 2015
Public Utilities, General Disclosures [Line Items]
Deferred revenues		$ 599,000,000	$ 599,000,000
Deferred revenues		$ 41,000,000	17,000,000	$ 20,000,000	$ 87,000,000
NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
Percentage of debt to total consolidated debt		20.00%
Maximum | NYSPSC
Public Utilities, General Disclosures [Line Items]
Percentage of total consolidated revenues		15.00%
O&R
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 3,000,000
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Deferred revenues		500,000	800,000			$ 800,000
Deferred revenues			6,300,000	1,700,000	6,200,000
Negative revenue adjustments		200,000	100,000	0	0	0
Cost reconciliation, deferred net regulatory liabilities		1,800,000	6,000,000	7,400,000	3,500,000					$ 4,500,000
Cost reconciliation, deferred net regulatory assets						$ 6,600,000
Deferred regulatory asset (liability)			(400,000)
Authorized return on common equity (percent)								9.00%
Earnings sharing (percent)								9.60%
Earnings sharing, threshold limit				$ 200,000	$ 4,000,000
Common Equity Ratio, Percentage								4800.00%
O&R | Gas | NYSPSC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Common Equity Ratio, Percentage	50.00%
Requested rate increase (decrease), amount	$ 9,800,000
Return on common equity (percent)	9.50%
O&R | Gas | Property Tax and Interest Rate Reconciliations
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable								$ 14,000,000
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained									$ 4,000,000.0
Share in variances in annual revenue retained (percent)							20.00%
Potential earnings adjustment mechanism incentives							$ 300,000
Authorized return on common equity (percent)							9.00%
Earnings sharing (percent)									9.60%
Common Equity Ratio, Percentage							4800.00%
O&R | Gas | Scenario, Forecast | Customers
Public Utilities, General Disclosures [Line Items]
Share in variances in annual revenue retained (percent)							80.00%
O&R | Gas | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes								16,400,000
Amortization to income of net regulatory assets								1,700,000
Net utility plant reconciliations								492,000,000
Average rate base								$ 366,000,000
Weighted average cost of capital (after-tax) (percent)								7.10%
Actual return on common equity (percent)								11.20%
Cost of long-term debt (percent)								5.42%
Rate exclusion amount with balance below regulatory threshold								$ 500,000
O&R | Gas | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								3,700,000
O&R | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							$ (7,500,000)
Amortization to income of net regulatory assets							1,800,000
Potential earnings adjustment mechanism incentives							1,200,000
Net utility plant reconciliations							593,000,000
Average rate base							$ 454,000,000
Weighted average cost of capital (after-tax) (percent)							6.97%
Actual return on common equity (percent)							8.90%
Cost of long-term debt (percent)							5.17%
Requested rate increase (decrease), amount							$ (5,900,000)
O&R | Gas | Year 1 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							20,000,000
O&R | Gas | Year 1 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							5,500,000
O&R | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes								16,400,000
Amortization to income of net regulatory assets								2,100,000
Net utility plant reconciliations								518,000,000
Average rate base								$ 391,000,000
Weighted average cost of capital (after-tax) (percent)								7.06%
Actual return on common equity (percent)								9.70%
Cost of long-term debt (percent)								5.35%
Rate exclusion amount with balance below regulatory threshold								$ 4,200,000
O&R | Gas | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								4,700,000
O&R | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							3,600,000
Amortization to income of net regulatory assets							1,800,000
Potential earnings adjustment mechanism incentives							1,300,000
Net utility plant reconciliations							611,000,000
Average rate base							$ 476,000,000
Weighted average cost of capital (after-tax) (percent)							6.96%
Actual return on common equity (percent)							9.58%
Cost of long-term debt (percent)							5.14%
Requested rate increase (decrease), amount							$ 1,000,000.0
O&R | Gas | Year 2 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							24,000,000
O&R | Gas | Year 2 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							5,700,000
O&R | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes								5,800,000
Base rate change through surcharge								10,600,000
Amortization to income of net regulatory assets								2,500,000
Net utility plant reconciliations								546,000,000
Average rate base								$ 417,000,000
Weighted average cost of capital (after-tax) (percent)								7.06%
Actual return on common equity (percent)								8.10%
Cost of long-term debt (percent)								5.35%
Rate exclusion amount with balance below regulatory threshold								$ 7,200,000
O&R | Gas | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)								$ 4,900,000
O&R | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes							700,000
Amortization to income of net regulatory assets							1,800,000
Potential earnings adjustment mechanism incentives							1,300,000
Net utility plant reconciliations							632,000,000
Average rate base							$ 498,000,000
Weighted average cost of capital (after-tax) (percent)							6.96%
Cost of long-term debt (percent)							5.14%
Requested rate increase (decrease), amount							$ 1,000,000.0
O&R | Gas | Year 3 | Scenario, Forecast | AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations							25,000,000
O&R | Gas | Year 3 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							$ 6,000,000.0
Energy Efficiency | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		300,000
Service Termination | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		$ 500,000	$ 700,000

XML

Regulatory Matters - Summary of Utilities Rate Plans (RECO) (Details) - RECO - USD ($) $ in Millions	1 Months Ended			3 Months Ended	9 Months Ended	35 Months Ended
	Feb. 29, 2020	Apr. 30, 2017	Jan. 31, 2016	Mar. 31, 2017	Dec. 31, 2017	Jan. 31, 2020
Public Utilities, General Disclosures [Line Items]
Utilities operating expense, depreciation and amortization						$ 0.2
Regulatory liabilities, amortization period						3 years
Amortization to income of net regulatory assets	$ 4.8					$ 25.6
Regulatory assets, amortization period	4 years					4 years
Average rate base	$ 229.9					$ 178.7
Weighted average cost of capital (after-tax) (percent)	711.00%					7.47%
Authorized return on common equity (percent)	950.00%					960.00%
Cost of long-term debt (percent)	488.00%					537.00%
Common Equity Ratio, Percentage	4832.00%					4970.00%
FERC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount		$ 17.7		$ 11.8
Return on common equity (percent)					10.00%
Electric
Public Utilities, General Disclosures [Line Items]
Plan electric system storm hardening amount			$ 15.7
Plan period (years)			3 years
Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes	$ 12.0					$ 1.7
Actual return on common equity (percent)	5.40%					7.50%
Year 2
Public Utilities, General Disclosures [Line Items]
Actual return on common equity (percent)						5.70%

XML

Regulatory Matters - COVID-19 Regulatory Matters (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Public Utilities, General Disclosures [Line Items]
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic		$ 78.0
CECONY
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		46.0
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic		73.0
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		34.0	$ 43.0	$ 25.0	$ 13.0
O&R
Public Utilities, General Disclosures [Line Items]
Actual earnings adjustment mechanism incentives		3.0
COVID-19
Public Utilities, General Disclosures [Line Items]
Deferred costs	$ 0.5	0.5
COVID-19 | CECONY
Public Utilities, General Disclosures [Line Items]
Estimated forgone revenues	61.0	3.0
COVID-19 | CECONY | Electric and Gas Transmission Projects
Public Utilities, General Disclosures [Line Items]
Reserve adjustments		73.0
Allowance for credit loss, write-off		18.0
COVID-19 | O&R | Gas
Public Utilities, General Disclosures [Line Items]
Reserve adjustments		2.0
Increase in allowance for uncollectible accounts resulting from COVID-19 pandemic		1.0
Allowance for credit loss, write-off		1.0
Residential Customers | COVID-19 | CECONY
Public Utilities, General Disclosures [Line Items]
Deferred revenue	54.9	$ 54.9
Summer Cooling Credit Program | Residential Customers | COVID-19 | CECONY
Public Utilities, General Disclosures [Line Items]
Cost of the program, recovery period		5 years
Expected deferred revenue	$ 63.4	$ 63.4

XML

Regulatory Matters - Additional Information (Details) customer in Thousands, $ in Thousands		1 Months Ended				3 Months Ended	9 Months Ended	12 Months Ended			36 Months Ended
	Jul. 13, 2019 customer	Nov. 30, 2020 USD ($) claim	Aug. 31, 2020 USD ($) customer	Mar. 31, 2018 customer	Apr. 30, 2017 USD ($)	Mar. 31, 2017 USD ($)	Dec. 31, 2017	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2022 USD ($)	Jun. 30, 2020 USD ($)	Apr. 30, 2020 USD ($)	Mar. 31, 2020 USD ($)	Jul. 31, 2019 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities								$ 4,513,000	$ 4,827,000
Return On regulatory assets								$ 1,696,000	$ 1,188,000
Other Customer-Provided Capital rate								2.65%	4.20%
Future Income Tax
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities								$ 2,207,000	$ 2,426,000
Net Unbilled Revenue Deferrals
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities								198,000	199,000
RECO | Electric | Hurricane
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer				44
Restoration costs								17,000
RECO | FERC
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount					$ 17,700	$ 11,800
Return on common equity (percent)							10.00%
CECONY
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities								4,094,000	4,427,000
Return On regulatory assets								1,509,000	1,054,000
CECONY | Future Income Tax
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities								2,062,000	2,275,000
CECONY | Net Unbilled Revenue Deferrals
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities								198,000	199,000
CECONY | Electric | Hurricane
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer				209
Restoration costs								134,000
Operation and maintenance expenses								15,000
Operation and maintenance expenses charged against a storm reserve								84,000
Capital expenditures								29,000
Removal costs								6,000
CECONY | Electric | Tropical Storm [Member]
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer			330
Restoration costs								153,000
Operation and maintenance expenses								18,000
Operation and maintenance expenses charged against a storm reserve								77,000
Capital expenditures								58,000
Property damage, clean up and response costs								7,500
Estimate of possible loss		$ 102,300
Alleged number of claims, violations | claim		33
CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA											$ 377,000
TCJA, net benefit amortization, allocation period											3 years
CECONY | Electric | Scenario, Forecast | Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											$ 1,663,000
CECONY | Electric | Scenario, Forecast | Unprotected Portion
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period											5 years
Increase in regulatory liability resulting from TCJA											$ 784,000
CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA											$ 63,000
TCJA, net benefit amortization, allocation period											2 years
CECONY | Gas | Scenario, Forecast | Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											$ 725,000
CECONY | Gas | Scenario, Forecast | Unprotected Portion
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period											5 years
Increase in regulatory liability resulting from TCJA											$ 107,000
CECONY | NYSPSC | Steam
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA								$ 185,000		$ 15,000
Tax credit, amortization period								3 years
CECONY | NYSPSC | Electric | Hurricane
Public Utilities, General Disclosures [Line Items]
Loss contingency accrual								$ 5,600
Settlement agreement amount			$ 5,600
O&R | Electric | Hurricane
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer				93
Restoration costs								43,000
O&R | Electric | Tropical Storm [Member]
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer			200
Restoration costs								34,000
Operation and maintenance expenses charged against a storm reserve								26,000
Capital expenditures								8,000
Property damage, clean up and response costs								2,900
Estimate of possible loss		$ 19,000
Alleged number of claims, violations | claim		38
O&R | Electric and Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Income tax benefit to be credited to customers resulting from TCJA											$ 22,000
TCJA, net benefit amortization, allocation period											3 years
O&R | Electric and Gas | Scenario, Forecast | Protected Portion
Public Utilities, General Disclosures [Line Items]
Increase in regulatory liability resulting from TCJA											$ 123,000
O&R | Electric and Gas | Scenario, Forecast | Unprotected Portion
Public Utilities, General Disclosures [Line Items]
TCJA, net benefit amortization, allocation period											15 years
Increase in regulatory liability resulting from TCJA											$ 30,000
O&R | NYSPSC | Electric | Hurricane
Public Utilities, General Disclosures [Line Items]
Loss contingency accrual								$ 850
Settlement agreement amount			$ 850
Manhattan | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer	72
Estimate of possible loss															$ 24,800
Brooklyn | CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Number of customers affected with interrupted service | customer	30
Cumulative catch-up adjustment to revenue, modification of contract									(15,000)
Manhattan Steam Main Rupture | CECONY | NYSPSC
Public Utilities, General Disclosures [Line Items]
Property damage, clean up and response costs									17,000
Capital and retirement costs									9,000
Loss contingency accrual												$ 3,000	$ 15,000
Violations Of Gas Operator Qualification, Performance, And Inspection Requirements | CECONY | NYSPSC | Gas
Public Utilities, General Disclosures [Line Items]
Loss contingency accrual									$ 10,000					$ 5,000

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Regulatory Matters - Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	$ 6,195	$ 4,859
Regulatory assets – current	266	128
Total Regulatory Assets	6,461	4,987
Regulatory assets not earning return	4,766	3,799
Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3,241	2,541
Regulatory assets not earning return	3,241	2,541
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	865	732
Regulatory assets not earning return	855	727
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	356	321
Regulatory assets not earning return	336	296
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	315	71
Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	241	219
Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	195	77
MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	188	248
System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	124	131
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	120	83
Regulatory assets not earning return	120	83
COVID - 19 Deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	115	0
Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	62	75
Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	36	39
Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	32	35
Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	25	19
Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	21	28
Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	21	22
Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	20	21
Non-wire alternative projects
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	14
Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	3
Regulatory assets not earning return	0	3
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	200	180
Regulatory assets not earning return	24	21
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	190	128
Regulatory assets not earning return	190	128
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	76	0
CECONY
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	5,745	4,487
Regulatory assets – current	244	113
Total Regulatory Assets	5,989	4,600
Regulatory assets not earning return	4,481	3,546
CECONY | Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3,065	2,403
Regulatory assets not earning return	3,065	2,403
CECONY | Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	791	647
Regulatory assets not earning return	781	647
CECONY | Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	342	308
Regulatory assets not earning return	323	285
CECONY | Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	272	47
CECONY | Property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	239	210
CECONY | Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	83	0
CECONY | MTA power reliability deferral
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	188	248
CECONY | System peak reduction and energy efficiency programs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	124	130
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	111	76
Regulatory assets not earning return	111	76
CECONY | COVID - 19 Deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	113	0
CECONY | Municipal infrastructure support costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	62	75
CECONY | Brooklyn Queens demand management program
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	36	39
CECONY | Meadowlands heater odorization project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	32	35
CECONY | Gate station upgrade project
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	25	19
CECONY | Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	19	26
CECONY | Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	21	22
CECONY | Recoverable REV demonstration project costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	19
CECONY | Non-wire alternative projects
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	18	14
CECONY | Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	3
Regulatory assets not earning return	0	3
CECONY | Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	186	166
Regulatory assets not earning return	24	20
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	177	113
Regulatory assets not earning return	177	112
CECONY | Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – current	$ 67	$ 0

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Regulatory Matters - Regulatory Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 4,513	$ 4,827
Regulatory liabilities—current	36	102
Total Regulatory Liabilities	4,549	4,929
Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	2,207	2,426
Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,090	989
TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	295	471
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	198	199
Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	137	173
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	85	75
System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	64	48
Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	36	45
BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	27	27
Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	21	10
Sales and use tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	16	8
Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	15	22
Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	11	9
Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5	8
Workers’ compensation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	3	0
Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1	122
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	302	195
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	28	44
Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	8	34
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	0	24
CECONY
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	4,094	4,427
Regulatory liabilities—current	11	63
Total Regulatory Liabilities	4,105	4,490
CECONY | Future income tax
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	2,062	2,275
CECONY | Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	932	843
CECONY | TCJA net benefits
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	286	454
CECONY | Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	198	199
CECONY | Net proceeds from sale of property
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	137	173
CECONY | Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	46	46
CECONY | System benefit charge carrying charge
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	57	44
CECONY | Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	35	45
CECONY | BQDM and REV Demo reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	25	26
CECONY | Settlement of gas proceedings
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	21	10
CECONY | Sales and use tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	16	8
CECONY | Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	10	15
CECONY | Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	0
CECONY | Settlement of prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	5	8
CECONY | Workers’ compensation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	3	0
CECONY | Energy efficiency portfolio standard unencumbered funds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	118
CECONY | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	261	163
CECONY | Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	4	12
CECONY | Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	7	34
CECONY | Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	$ 0	$ 17

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Capitalization - Common Stock (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Dec. 31, 2020	Jan. 31, 2020	Jun. 30, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	May 31, 2019	Dec. 31, 2017
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)	500,000,000			500,000,000
Common stock, shares outstanding (in shares)	342,297,534			342,297,534	332,629,597
Treasury shares (in shares)	23,210,700			23,210,700	23,210,700
Value of shares issued				$ 640	$ 825	$ 705
Proceeds from issuance of common stock				$ 640	$ 825	$ 705
0.65 Percent Debentures Due 2023 | Debentures
Schedule of Capitalization [Line Items]
Interest rate	0.65%			0.65%
Proceeds from sale of aggregate principal amount	$ 650
Term Loan Due July 2020 | Term Loan
Schedule of Capitalization [Line Items]
Repayments of debt	$ 820
Common Stock
Schedule of Capitalization [Line Items]
Common stock, shares outstanding (in shares)	342,000,000			342,000,000	333,000,000	321,000,000		310,000,000
Shares issued (in shares)	7,200,000			9,000,000	12,000,000	11,000,000
Value of shares issued				$ 1	$ 1
Proceeds from issuance of common stock	$ 553
Forward Contract | Common Stock
Schedule of Capitalization [Line Items]
Common stock, shares subject to forward sale agreements (in shares)							5,800,000
Shares issued (in shares)		1,050,000	4,750,000
Value of shares issued		$ 88	$ 400
CECONY
Schedule of Capitalization [Line Items]
Common stock, shares authorized (in shares)	340,000,000			340,000,000
Common stock, shares outstanding (in shares)	235,488,094			235,488,094	235,488,094
Treasury shares (in shares)	21,976,200			21,976,200	21,976,200
CECONY | Common Stock
Schedule of Capitalization [Line Items]
Common stock, shares outstanding (in shares)	235,000,000			235,000,000	235,000,000	235,000,000		235,000,000

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Capitalization - Dividends (Details)	12 Months Ended
	Dec. 31, 2020
Debt Disclosure [Abstract]
Percentage limitation for income available for dividends (not more than)	100.00%
Rolling average calculation of income available for dividends (years)	2 years

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Capitalization - Schedule of Long-Term Debt Maturities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
2021	$ 1,967
2022	437
2023	966
2024	385
2025	315
Long-term debt	22,349	$ 19,973
Long-term debt due within one year		1,446
CECONY
Debt Instrument [Line Items]
2021	640
2022	0
2024	250
2025	0
Long-term debt	$ 16,789	14,964
Long-term debt due within one year		$ 350

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Capitalization - Long-term Debt, Additional Information (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Long-term debt	$ 22,349,000,000	$ 19,973,000,000
CECONY
Debt Instrument [Line Items]
Long-term debt	16,789,000,000	14,964,000,000
CECONY | Tax-Exempt Debt
Debt Instrument [Line Items]
Debt instrument, face amount	450,000,000
Long-term debt	$ 450,000,000	$ 450,000,000

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Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Unamortized debt expense	$ 215	$ 178
Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	22,349	19,973
Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	26,808	22,738
CECONY
Debt Instrument [Line Items]
Unamortized debt discount	176	151
CECONY | Carrying Amount
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	16,789	14,964
CECONY | Fair Value
Debt Instrument [Line Items]
Long-Term Debt (including current portion)	$ 20,974	$ 17,505

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Capitalization - Significant Debt Covenants (Details)	12 Months Ended
	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Debt Instrument [Line Items]
Long-term debt	$ 22,349,000,000	$ 19,973,000,000
Maximum ratio of consolidated debt to consolidated total capital	0.53
CECONY
Debt Instrument [Line Items]
Long-term debt	$ 16,789,000,000	14,964,000,000
Maximum ratio of consolidated debt to consolidated total capital	0.56
Term Loan
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.65
Covenant principal balance amount limit	$ 150,000,000
Term Loan | Term Loan Due June 2021
Debt Instrument [Line Items]
Debt instrument, face amount	825,000,000
Long-term debt	675,000,000
Term Loan | CECONY
Debt Instrument [Line Items]
Covenant principal balance amount limit	$ 150,000,000
Notes
Debt Instrument [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.675
Covenant principal balance amount limit	$ 100,000,000
Notes | CECONY
Debt Instrument [Line Items]
Covenant principal balance amount limit	100,000,000
Tax-Exempt Debt | CECONY
Debt Instrument [Line Items]
Debt instrument, face amount	450,000,000
Long-term debt	$ 450,000,000	$ 450,000,000
Maximum ratio of consolidated debt to consolidated total capital	0.65

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Short-Term Borrowing (Details)	12 Months Ended
	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 1,705,000,000	$ 1,692,000,000
Weighted average interest rate	0.30%	2.00%
Loans outstanding under credit agreement	$ 0	$ 0
Maximum ratio of consolidated debt to consolidated total capital	0.53
Minimum percentage of liens on assets	5.00%
Failure to pay, maximum aggregate limit	$ 150,000,000
Maximum
Short-term Debt [Line Items]
Maximum ratio of consolidated debt to consolidated total capital	0.65
Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 1,500,000,000
Current amount available	1,000,000,000
Letters of Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	1,200,000,000
CECONY
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 1,660,000,000	$ 1,137,000,000
Weighted average interest rate	0.30%	2.00%
Maximum ratio of consolidated debt to consolidated total capital	0.56
Credit Availability Through December 2022 | CECONY | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 2,250,000,000
Credit Availability Through December 2023 | CECONY | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	2,200,000,000
Variable Rate Construction Loan Facility Due November 2021 | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	613,000,000
Variable Rate Construction Loan Facility Due November 2021 | Revolving Credit | Clean Energy Businesses
Short-term Debt [Line Items]
Debt instrument, face amount	$ 165,000,000

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Pension Benefits - Total Periodic Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 293	$ 250	$ 290
Interest cost on projected benefit obligation	549	601	561
Expected return on plan assets	(1,034)	(988)	(1,033)
Recognition of net actuarial loss	699	518	688
Recognition of prior service credit	(16)	(17)	(17)
TOTAL PERIODIC BENEFIT COST	491	364	489
Cost capitalized	(130)	(108)	(127)
Reconciliation to rate level	(250)	(15)	(92)
Total credit recognized	111	241	270
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	274	232	272
Interest cost on projected benefit obligation	515	564	525
Expected return on plan assets	(980)	(936)	(979)
Recognition of net actuarial loss	661	492	651
Recognition of prior service credit	(19)	(19)	(19)
TOTAL PERIODIC BENEFIT COST	451	333	450
Cost capitalized	(123)	(102)	(119)
Reconciliation to rate level	(239)	(12)	(100)
Total credit recognized	$ 89	$ 219	$ 231

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Pension Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 397
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	465	$ 397
Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	16,792	14,449	$ 15,536
Service cost – excluding administrative expenses	288	245	286
Interest cost on projected benefit obligation	549	601	561
Net actuarial loss/(gain)	2,281	2,191	(1,219)
Plan amendments	0	15	0
Benefits paid	(945)	(709)	(715)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	18,965	16,792	14,449
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	15,608	13,450	14,274
Actual return on plan assets	1,927	2,556	(536)
Employer contributions	475	350	473
Benefits paid	(945)	(709)	(715)
Administrative expenses	(43)	(39)	(46)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	17,022	15,608	13,450
FUNDED STATUS	(1,943)	(1,184)	(999)
Unrecognized net loss	3,330	2,604	2,464
Unrecognized prior service costs/(credits)	(156)	(173)	(205)
Accumulated benefit obligation	16,768	15,015	13,030
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	371
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	439	371
CECONY | Pension Benefits
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	15,750	13,542	14,567
Service cost – excluding administrative expenses	269	228	267
Interest cost on projected benefit obligation	515	564	525
Net actuarial loss/(gain)	2,154	2,076	(1,159)
Plan amendments	0	0	0
Benefits paid	(867)	(660)	(658)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	17,821	15,750	13,542
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	14,790	12,744	13,519
Actual return on plan assets	1,830	2,425	(507)
Employer contributions	435	318	434
Benefits paid	(867)	(660)	(658)
Administrative expenses	(41)	(37)	(44)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	16,147	14,790	12,744
FUNDED STATUS	(1,674)	(960)	(798)
Unrecognized net loss	3,145	2,466	2,338
Unrecognized prior service costs/(credits)	(183)	(202)	(222)
Accumulated benefit obligation	$ 15,676	$ 14,010	$ 12,161

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Pension Benefits - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Pension liability	$ 759,000,000	$ 185,000,000
Investments value	465,000,000	397,000,000
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets and liabilities for future income taxes, net	734,000,000
Charge to OCI	8,000,000
Investments value	17,022,000,000	15,608,000,000	$ 13,450,000,000	$ 14,274,000,000
Accumulated benefit obligation	16,768,000,000	15,015,000,000	13,030,000,000
Defined benefit plan, bond amount (excess of)	50,000,000
Estimated future employer contributions	480,000,000
Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	414,000,000	395,000,000
CECONY
Defined Benefit Plan Disclosure [Line Items]
Pension liability	714,000,000	162,000,000
Investments value	439,000,000	371,000,000
CECONY | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets and liabilities for future income taxes, net	696,000,000
Charge to OCI	2,000,000
Investments value	16,147,000,000	14,790,000,000	12,744,000,000	$ 13,519,000,000
Accumulated benefit obligation	15,676,000,000	14,010,000,000	$ 12,161,000,000
Estimated future employer contributions	441,000,000
CECONY | Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 377,000,000	$ 360,000,000

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Pension Benefits - Schedule of Assumptions (Details)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CECONY
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.80%	3.80%	4.25%
Rate of compensation increase	3.80%	4.25%	4.25%
O&R
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3.20%	3.20%	4.00%
Rate of compensation increase	3.20%	4.00%	4.00%
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations	2.55%	3.35%	4.25%
Interest crediting rate for cash balance plan	3.00%	3.30%	4.00%
Discount rate, net periodic benefit cost	3.35%	4.25%	3.70%
Interest crediting rate for cash balance plan	3.30%	4.00%	4.10%
Expected return on plan assets	7.00%	7.00%	7.50%

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Pension Benefits - Schedule of Expected Benefit Payments (Details) - Pension Benefits $ in Millions	Dec. 31, 2020 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2020	$ 764
2021	776
2022	793
2023	807
2024	821
2026-2030	4,295
CECONY
Defined Benefit Plan Disclosure [Line Items]
2020	706
2021	718
2022	733
2023	747
2024	760
2026-2030	$ 3,992

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Pension Benefits - Schedule of Plan Assets Allocations (Details) - Pension Benefits	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	100.00%
Plan Assets Percentage	100.00%	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	51.00%	51.00%	51.00%
Equity Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	45.00%
Equity Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	55.00%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	38.00%	38.00%	39.00%
Debt Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	33.00%
Debt Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	43.00%
Real Estate
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	11.00%	11.00%	10.00%
Real Estate | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	10.00%
Real Estate | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	14.00%

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Pension Benefits - Schedule of Fair Value of Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 465	$ 397
Private Equity
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Real Estate
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 17,022	$ 15,608	$ 13,450	$ 14,274
Pension Benefits | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,202	3,652
Pension Benefits | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,693	3,354
Pension Benefits | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,424	1,496
Pension Benefits | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,535	3,260
Pension Benefits | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	188	173
Pension Benefits | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,067	955
Pension Benefits | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	459	326
Pension Benefits | Private Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	635	555
Pension Benefits | Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,880	1,806
Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	292	270
Pension Benefits | Total Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(254)	(250)
Pension Benefits | Pending Activities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(99)	11
Pension Benefits | Fair Value, Inputs, Level 1 and 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	14,568	13,216
Pension Benefits | Fair Value, Inputs, Level 1 and 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(213)	(208)
Pension Benefits | Fair Value, Inputs, Level 1 and 2 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	17,121	15,597
Pension Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,946	7,006
Pension Benefits | Level 1 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	4,202	3,652
Pension Benefits | Level 1 | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,693	3,354
Pension Benefits | Level 1 | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 1 | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 1 | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 1 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 1 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	51
Pension Benefits | Level 1 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(116)	(110)
Pension Benefits | Level 1 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,830	6,896
Pension Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	6,622	6,210
Pension Benefits | Level 2 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Pension Benefits | Level 2 | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,424	1,496
Pension Benefits | Level 2 | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,535	3,260
Pension Benefits | Level 2 | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	188	173
Pension Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,067	955
Pension Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	408	326
Pension Benefits | Level 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	(97)	(98)
Pension Benefits | Level 2 | Investments Excluding Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	6,525	6,112
Pension Benefits | Fair Value Measured at Net Asset Value Per Share | Investments Valued Using NAV Per Share
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,807	2,631
Pension Benefits | Fair Value Measured at Net Asset Value Per Share | Funds For Retiree Health Benefits Measured At Net Asset Value
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ (41)	$ (42)

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Pension Benefits - Schedule of Employer Contribution to Defined Savings Plan (Details) - Defined Contribution Savings Plan - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 52	$ 49	$ 45
CECONY
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 43	$ 42	$ 39

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Other Postretirement Benefits - Net Periodic Postretirement Benefit Costs (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 21	$ 18	$ 20
Interest cost on accumulated other postretirement benefit obligation	37	44	42
Expected return on plan assets	(66)	(66)	(73)
Recognition of net actuarial loss/(gain)	37	(9)	8
Recognition of prior service credit	(3)	(2)	(6)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	26	(15)	(9)
Cost capitalized	(9)	(7)	(8)
Reconciliation to rate level	(17)	12	8
Total credit recognized	0	(10)	(9)
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	16	13	14
Interest cost on accumulated other postretirement benefit obligation	31	36	34
Expected return on plan assets	(54)	(54)	(63)
Recognition of net actuarial loss/(gain)	36	(10)	3
Recognition of prior service credit	(2)	(2)	(2)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST/(CREDIT)	27	(17)	(14)
Cost capitalized	(7)	(5)	(6)
Reconciliation to rate level	(25)	7	9
Total credit recognized	$ (5)	$ (15)	$ (11)

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Other Postretirement Benefits - Schedule of Funded Status (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$ 397
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	465	$ 397
CECONY
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	371
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	439	371
Other Postretirement Benefits
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,357	1,114	$ 1,219
Service cost	21	18	20
Interest cost on accumulated other postretirement benefit obligation	37	44	42
Amendments	0	(14)	0
Net actuarial loss/(gain)	74	264	(70)
Benefits paid and administrative expenses, net of subsidies	(117)	(110)	(135)
Participant contributions	53	41	38
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,425	1,357	1,114
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	1,026	885	1,039
Actual return on plan assets	142	198	(66)
Employer contributions	7	7	6
Employer group waiver plan subsidies	20	23	34
Participant contributions	53	40	37
Benefits paid	(133)	(127)	(165)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	1,115	1,026	885
FUNDED STATUS	(310)	(331)	(229)
Unrecognized net loss/(gain)	115	155	14
Unrecognized prior service costs	(16)	(19)	(8)
Other Postretirement Benefits | CECONY
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,154	913	985
Service cost	16	13	14
Interest cost on accumulated other postretirement benefit obligation	31	36	34
Amendments	0	0	0
Net actuarial loss/(gain)	63	252	(32)
Benefits paid and administrative expenses, net of subsidies	(107)	(100)	(125)
Participant contributions	52	40	37
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,209	1,154	913
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	872	759	893
Actual return on plan assets	117	165	(54)
Employer contributions	4	6	6
Employer group waiver plan subsidies	19	22	32
Participant contributions	51	40	37
Benefits paid	(123)	(120)	(155)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	940	872	759
FUNDED STATUS	(269)	(282)	(154)
Unrecognized net loss/(gain)	114	149	(2)
Unrecognized prior service costs	$ (1)	$ (3)	$ (5)

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Other Postretirement Benefits - Additional Information (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in liability for other postretirement benefits	$ (21)	$ 102
Increase (decrease) in regulatory liabilities	$ 36
Health care cost trend rate for net periodic benefit cost, current	5.20%	5.40%	5.60%
Health care cost trend rate for net periodic benefit cost	4.50%
Health care cost trend rate for benefit obligations, current	7.04%	5.20%	5.40%
Health care cost trend rate for benefit obligations	4.50%
Expected contributions	$ 6
Clean Energy Businesses, Con Edison Transmission and RECO
Defined Benefit Plan Disclosure [Line Items]
Credit to OCI (net of taxes) for unrecognized net losses	2
CECONY
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in liability for other postretirement benefits	(13)	$ 128
Increase (decrease) in regulatory liabilities	33
Expected contributions	$ 3

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Other Postretirement Benefits - Schedule of Actuarial Assumptions (Details) - Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Expected Return on Plan Assets	6.80%	6.80%	7.50%
CECONY
Defined Benefit Plan Disclosure [Line Items]
Discount Rate, Benefit Obligations	2.25%	3.10%	4.15%
Discount Rate, Net Periodic Benefit Cost	3.10%	4.15%	3.55%
O&R
Defined Benefit Plan Disclosure [Line Items]
Discount Rate, Benefit Obligations	2.55%	3.35%	4.30%
Discount Rate, Net Periodic Benefit Cost	3.35%	4.30%	3.70%

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Other Postretirement Benefits - Schedule of Expected Benefit Payments (Details) - Other Postretirement Benefits $ in Millions	Dec. 31, 2020 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2020	$ 84
2021	84
2022	84
2023	84
2024	84
2026-2030	409
CECONY
Defined Benefit Plan Disclosure [Line Items]
2020	76
2021	75
2022	75
2023	75
2024	75
2026-2030	$ 358

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Other Postretirement Benefits - Schedule of Plan Assets Allocations (Details) - Other Postretirement Benefits - CECONY	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	100.00%
Plan Assets Percentage	100.00%	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	54.00%	54.00%	52.00%
Equity Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	42.00%
Equity Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	80.00%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	46.00%	46.00%	48.00%
Debt Securities | Minimum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	20.00%
Debt Securities | Maximum
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range	58.00%

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Other Postretirement Benefits - Schedule of Fair Values of Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 465	$ 397
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,115	1,026	$ 885	$ 1,039
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	842	758
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	448	404
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	367	331
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	27	23
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	213	208
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,055	966
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Funds For Retiree Health Benefits Measured At Net Asset Value
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	41	42
Other Postretirement Benefits | Fair Value, Inputs, Level 1 and 2 | Pending Activities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	19	18
Other Postretirement Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Other Postretirement Benefits | Level 1 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	116	110
Other Postretirement Benefits | Level 1 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	116	110
Other Postretirement Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	842	758
Other Postretirement Benefits | Level 2 | Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	448	404
Other Postretirement Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	367	331
Other Postretirement Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	27	23
Other Postretirement Benefits | Level 2 | Funds For Retiree Health Benefits
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	97	98
Other Postretirement Benefits | Level 2 | Investments, Including Funds For Retiree Health Benefit
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 939	$ 856

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Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Site Contingency [Line Items]
Accrued Liabilities	$ 857	$ 734
Regulatory assets	6,461	4,987
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	752	640
Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	105	94
Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	857	734
Regulatory assets	865	732
CECONY
Site Contingency [Line Items]
Accrued Liabilities	780	654
Regulatory assets	5,989	4,600
CECONY | Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	676	561
CECONY | Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	104	93
CECONY | Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	780	654
Regulatory assets	$ 791	$ 647

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Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 33	$ 19
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 32	$ 13

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Environmental Matters - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($)
Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)	15 years
CECONY | Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)	15 years
Superfund Sites
Site Contingency [Line Items]
Remediation cost estimate	$ 40
Superfund Sites | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	2,700
Superfund Sites | CECONY
Site Contingency [Line Items]
Remediation cost estimate	38
Superfund Sites | CECONY | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	$ 2,600

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Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Site Contingency [Line Items]
Regulatory Liabilities	$ (4,549)	$ (4,929)
Regulatory assets	6,461	4,987
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers' Compensation
Site Contingency [Line Items]
Accrued liability	72	78
Regulatory Liabilities	(3)
Regulatory assets		3
CECONY
Site Contingency [Line Items]
Regulatory Liabilities	(4,105)	(4,490)
Regulatory assets	5,989	4,600
CECONY | Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY | Workers' Compensation
Site Contingency [Line Items]
Accrued liability	68	73
Regulatory Liabilities	$ (3)
Regulatory assets		$ 3

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Material Contingencies - Manhattan Explosion and Fire (Details) $ in Millions		1 Months Ended
	Mar. 12, 2014 building people	Feb. 28, 2017 USD ($)	Dec. 31, 2020 USD ($) lawsuit	Oct. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 4,513		$ 4,827
Settlement of gas proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability			$ 21		$ 10
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
Insurance receivable				$ 40
Manhattan Explosion and Fire | Settlement of gas proceedings
Loss Contingencies [Line Items]
Accrued regulatory liability		$ 27

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Material Contingencies - Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Commitments and Contingencies Disclosure [Abstract]
Guarantee obligations maximum exposure	$ 2,042	$ 1,831

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Material Contingencies - Total Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 2,042	$ 1,831
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	570
Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	753
Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	649
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	1,228
0 – 3 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	393
0 – 3 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	480
0 – 3 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	285
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	237
4 – 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	177
4 – 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	51
4 – 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	9
4 – 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
> 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	577
> 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
> 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	222
> 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	355
> 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 0

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Material Contingencies - Con Edison Transmission (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,042	$ 1,831
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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Material Contingencies - Other (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 2,042	$ 1,831
Financial Guarantee for Indemnity Agreements for Surety Bonds in Connection with Operation of Solar Energy Facilities and Energy Service Projects
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure	$ 70

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Electricity Purchase Agreements - Summary of Estimated Capacity and Other Fixed Payments (Details) $ in Millions	Dec. 31, 2020 USD ($)
Long-term Contract for Purchase of Electric Power [Line Items]
2021	$ 141
2022	106
2023	68
2024	53
2025	54
All Years Thereafter	487
CECONY
Long-term Contract for Purchase of Electric Power [Line Items]
2021	138
2022	106
2023	68
2024	53
2025	54
All Years Thereafter	$ 487

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Electricity Purchase Agreements - Summary of Capacity, Energy and Other Fixed Payments (Details) - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 139	$ 231	$ 318
Indian Point
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	0	0	6
Astoria Generating Company
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	26	116	179
Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	113	115	124
Cogen Technologies
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 0	$ 0	$ 9

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Leases - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Lease, renewal term	5 years
Assets under finance leases	$ 3	$ 1
Finance leases, accumulated amortization	3	5
Right-of-use asset obtained in exchange for operating lease liability	23	39
CECONY
Lessee, Lease, Description [Line Items]
Assets under finance leases	2
Finance leases, accumulated amortization	1	3
Right-of-use asset obtained in exchange for operating lease liability	$ 11	$ 4
Minimum
Lessee, Lease, Description [Line Items]
Lease, term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Lease, term	40 years

XML

Leases - Lease Cost and Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 85	$ 83
Operating lease cash flows	79	75
CECONY
Lessee, Lease, Description [Line Items]
Operating lease cost	65	64
Operating lease cash flows	$ 61	$ 60

XML

Leases - Other Related Information (Details)	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	19 years 1 month 6 days	19 years 9 months 18 days
Weighted Average Remaining Lease Term, Finance leases	7 years 3 months 18 days	12 years 2 months 12 days
Weighted Average Discount Rate, Operating leases	4.30%	4.30%
Weighted Average Discount Rate, Finance leases	1.80%	3.50%
CECONY
Lessee, Lease, Description [Line Items]
Weighted Average Remaining Lease Term, Operating leases	13 years	14 years
Weighted Average Remaining Lease Term, Finance leases	4 years	2 years 4 months 24 days
Weighted Average Discount Rate, Operating leases	3.60%	3.60%
Weighted Average Discount Rate, Finance leases	1.30%	4.10%

XML

Leases - Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Operating Leases
2021	$ 79
2022	77
2023	74
2024	75
2025	75
All years thereafter	938
Total future minimum lease payments	1,318
Less: imputed interest	(458)
Total	860
Operating lease liabilities (current)	96	$ 65
Operating lease liabilities (noncurrent)	764	809
Total	860
Finance Leases
2021	1
2022	1
2023	0
2024	0
2025	0
All years thereafter	1
Total future minimum lease payments	3
Less: imputed interest	0
Total	3
Other current liabilities	1
Other noncurrent liabilities	2
Total	3
CECONY
Operating Leases
2021	62
2022	58
2023	57
2024	57
2025	58
All years thereafter	451
Total future minimum lease payments	743
Less: imputed interest	(158)
Total	585
Operating lease liabilities (current)	73	54
Operating lease liabilities (noncurrent)	512	$ 551
Total	585
Finance Leases
2021	1
2022	1
2023	0
2024	0
2025	0
All years thereafter	0
Total future minimum lease payments	2
Less: imputed interest	0
Total	2
Other current liabilities	1
Other noncurrent liabilities	1
Total	$ 2

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Goodwill (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Goodwill [Line Items]
Goodwill	$ 446	$ 446
CECONY
Goodwill [Line Items]
Goodwill	245	245
O&R
Goodwill [Line Items]
Goodwill	161	161
O&R Merger
Goodwill [Line Items]
Goodwill	406	406
Gas Storage Company | CET Gas
Goodwill [Line Items]
Goodwill	8	8
Residential Solar Company | Clean Energy Businesses
Goodwill [Line Items]
Goodwill	14	14
Battery Storage Company | Clean Energy Businesses
Goodwill [Line Items]
Goodwill	$ 18	$ 18

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Income Tax - Schedule of Components of Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
State
Current	$ 7	$ (12)	$ (10)
Deferred	50	96	107
Federal
Current	(2)	0	3
Deferred	42	219	310
Amortization of investment tax credits	(7)	(7)	(9)
Total income tax expense	90	296	401
CECONY
State
Current	6	22	6
Deferred	97	68	82
Federal
Current	41	185	(34)
Deferred	73	63	275
Amortization of investment tax credits	(2)	(3)	(3)
Total income tax expense	$ 215	$ 335	$ 326

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Income Tax - Schedule of Differences on Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Deferred tax liabilities:
Property basis differences	$ 7,985	$ 7,699
Regulatory assets:
Unrecognized pension and other postretirement costs	910	712
Environmental remediation costs	243	205
Deferred storm costs	31	22
Other regulatory assets	536	376
Operating lease right-of-use asset	220	231
Equity investments	46	104
Total deferred tax liabilities	9,971	9,349
Deferred tax assets:
Accrued pension and other postretirement costs	504	291
Future income tax	617	678
Other regulatory liabilities	656	702
Superfund and other environmental costs	241	206
Asset retirement obligations	178	135
Operating lease liabilities	211	231
Loss carryforwards	164	108
Tax credits carryforward	1,022	896
Valuation allowance	(22)	(31)
Other	59	47
Total deferred tax assets	3,630	3,263
Net deferred tax liabilities	6,341	6,086
Unamortized investment tax credits	134	141
Net deferred tax liabilities and unamortized investment tax credits	6,475	6,227
CECONY
Deferred tax liabilities:
Property basis differences	6,901	6,640
Regulatory assets:
Unrecognized pension and other postretirement costs	861	674
Environmental remediation costs	222	181
Deferred storm costs	0	0
Other regulatory assets	508	355
Operating lease right-of-use asset	165	169
Equity investments	0	0
Total deferred tax liabilities	8,657	8,019
Deferred tax assets:
Accrued pension and other postretirement costs	427	222
Future income tax	579	638
Other regulatory liabilities	570	622
Superfund and other environmental costs	219	183
Asset retirement obligations	143	102
Operating lease liabilities	165	170
Loss carryforwards	34	0
Tax credits carryforward	0	0
Valuation allowance	0	0
Other	127	103
Total deferred tax assets	2,264	2,040
Net deferred tax liabilities	6,393	5,979
Unamortized investment tax credits	18	21
Net deferred tax liabilities and unamortized investment tax credits	$ 6,411	$ 6,000

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Income Tax - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	$ 21.0
Unrecognized Tax Benefits	14.0	$ 13.0	$ 6.0	$ 12.0
Effective income tax rate reconciliation, uncertainty of taxes	3.0
Unrecognized tax benefits that would have an impact on effective tax rate	14.0
Unrecognized tax benefits that would have an impact on effective tax rate, net of tax	13.0
General Business Tax Credit
Operating Loss Carryforwards [Line Items]
Tax credit carryovers	1,022.0
Tax Year 2018 Through 2013
Operating Loss Carryforwards [Line Items]
Operating loss carryback	29.0
Net tax refund	2.5
Tax Year 2013
Operating Loss Carryforwards [Line Items]
Discrete income tax benefit	4.0
State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards, valuation allowance	18.0
State | New York State
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards	1,351.0
State | New York City
Operating Loss Carryforwards [Line Items]
Valuation allowance reversed	$ 9.0
Deferred tax asset, period of realization	10 years
CECONY
Operating Loss Carryforwards [Line Items]
Unrecognized Tax Benefits	$ 3.0	$ 2.0	$ 4.0	$ 5.0
Effective income tax rate reconciliation, uncertainty of taxes	1.0
Unrecognized tax benefits that would have an impact on effective tax rate	$ 3.0

XML

Income Tax - Schedule of Income Tax Reconciliation (Details)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
STATUTORY TAX RATE
Federal	21.00%	21.00%	21.00%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	4.00%	4.00%	4.00%
Taxes attributable to noncontrolling interests	(1.00%)	(1.00%)	0.00%
Cost of removal	2.00%	1.00%	1.00%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)
TCJA deferred tax re-measurement	0	0	0.02
Amortization of excess deferred federal income taxes	(14.00%)	(4.00%)	(3.00%)
Renewable energy credits	(3.00%)	(2.00%)	(1.00%)
Research and development credits	0.00%	(1.00%)	0.00%
Other	(1.00%)	0.00%	0.00%
Effective tax rate	7.00%	17.00%	23.00%
CECONY
STATUTORY TAX RATE
Federal	21.00%	21.00%	21.00%
Changes in computed taxes resulting from:
State income taxes, net of federal income tax benefit	5.00%	5.00%	5.00%
Taxes attributable to noncontrolling interests	0.00%	0.00%	0.00%
Cost of removal	1.00%	1.00%	1.00%
Other plant-related items	(1.00%)	(1.00%)	(1.00%)
TCJA deferred tax re-measurement	0	0	0
Amortization of excess deferred federal income taxes	(12.00%)	(4.00%)	(3.00%)
Renewable energy credits	0.00%	0.00%	0.00%
Research and development credits	0.00%	(1.00%)	(1.00%)
Other	1.00%	0.00%	(1.00%)
Effective tax rate	15.00%	21.00%	21.00%

XML

Income Tax - Summary of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	$ 13	$ 6	$ 12
Additions based on tax positions related to the current year	0	1	2
Additions based on tax positions of prior years	1	10	1
Reductions for tax positions of prior years	0	(2)	(2)
Reductions from expiration of statute of limitations	0	0	(4)
Settlements	0	(2)	(3)
Balance at end of period	14	13	6
CECONY
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	2	4	5
Additions based on tax positions related to the current year	0	1	2
Additions based on tax positions of prior years	1	0	1
Reductions for tax positions of prior years	0	(1)	(1)
Reductions from expiration of statute of limitations	0	0	0
Settlements	0	(2)	(3)
Balance at end of period	$ 3	$ 2	$ 4

XML

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 12,026	$ 12,144	$ 11,928
Revenues	12,246	12,574	12,337	$ 12,033
Other
Disaggregation of Revenue [Line Items]
Revenues	220	430	409
Clean Energy Businesses | Renewables [Member] | Engineering, procurement and construction
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8	14	103
CECONY
Disaggregation of Revenue [Line Items]
Revenues	10,647	10,821	10,680
Operating Segments | Clean Energy Businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	661	646	424
Revenues	736	857	763
Operating Segments | Clean Energy Businesses | Other
Disaggregation of Revenue [Line Items]
Revenues	75	211	339
Operating Segments | Clean Energy Businesses | Renewables [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	609	575	329
Revenues	609	575	329
Operating Segments | Clean Energy Businesses | Renewables [Member] | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Energy Service [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	52	71	95
Revenues	52	71	95
Operating Segments | Clean Energy Businesses | Energy Service [Member] | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | Clean Energy Businesses | Other Services [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Revenues	75	211	339
Operating Segments | Clean Energy Businesses | Other Services [Member] | Other
Disaggregation of Revenue [Line Items]
Revenues	75	211	339
Operating Segments | Con Edison Transmission
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4	4	4
Revenues	4	4	4
Operating Segments | Con Edison Transmission | Other
Disaggregation of Revenue [Line Items]
Revenues	0	0	0
Operating Segments | CECONY
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	10,518	10,620	10,597
Revenues	10,647	10,821	10,680
Operating Segments | CECONY | Other
Disaggregation of Revenue [Line Items]
Revenues	129	201	83
Operating Segments | CECONY | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	8,026	7,913	7,920
Revenues	8,103	8,062	7,971
Operating Segments | CECONY | Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	77	149	51
Operating Segments | CECONY | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,998	2,097	2,052
Revenues	2,036	2,132	2,078
Operating Segments | CECONY | Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	38	35	26
Operating Segments | CECONY | Steam
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	494	610	625
Revenues	508	627	631
Operating Segments | CECONY | Steam | Other
Disaggregation of Revenue [Line Items]
Revenues	14	17	6
Operating Segments | O&R
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	843	874	903
Revenues	862	893	891
Operating Segments | O&R | Other
Disaggregation of Revenue [Line Items]
Revenues	19	19	(12)
Operating Segments | O&R | Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	619	627	647
Revenues	629	634	642
Operating Segments | O&R | Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	10	7	(5)
Operating Segments | O&R | Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	224	247	256
Revenues	233	259	249
Operating Segments | O&R | Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	9	12	(7)
Other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Revenues	(3)	(1)	(1)
Other | Other
Disaggregation of Revenue [Line Items]
Revenues	(3)	(1)	(1)
Other | O&R
Disaggregation of Revenue [Line Items]
Revenues	$ 0	$ 0	$ 0

XML

Revenue Recognition - Change in Unbilled Contract and Unearned Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Unbilled contract revenue
Beginning balance	$ 29	$ 29	$ 58
Additions	88	86	144
Subtractions	106	86	173
Ending balance	11	29	29
Unearned revenue
Beginning balance	17	20	87
Additions	31	1	38
Subtractions	7	4	105
Ending balance	41	17	20
Contracts with customer, revenue recognized, amount outstanding end of last period	$ 7	$ 4	$ 50

XML

Revenue Recognition - Revenue Recognition, Remaining Performance Obligation (Details) $ in Millions	Dec. 31, 2020 USD ($)
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 216
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue from Contract with Customer [Abstract]
Remaining performance obligation	$ 181
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	$ 35
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Expected timing of satisfaction

XML

Revenue Recognition - Additional information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($)
Disaggregation of Revenue [Line Items]
Late fee and other fees not collected	$ 64
CECONY
Disaggregation of Revenue [Line Items]
Late fee and other fees not collected	$ 61

XML

Stock-Based Compensation - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit realized from stock options exercised	$ 5,000,000	$ 13,000,000	$ 4,000,000
Maximum employer contribution match (up to)	1
Amount employee contribution for employer match	9
Maximum employee investment per year (up to)	$ 25,000
Maximum percentage allowed to invest (not more than)	20.00%
CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit realized from stock options exercised	$ 4,000,000	11,000,000	4,000,000
Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock received upon vesting (in shares)	1
Compensation expense to be recognized	$ 21,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 21,000,000	24,000,000	29,000,000
Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 17,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 18,000,000	22,000,000	28,000,000
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period (years)	3 years
Time-based Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 2,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 1,000,000	1,000,000	1,000,000
Weighted average grant date price per share (in dollars per share)	$ 78.00
Time-based Awards | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 2,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Payment for settlement of vested units	$ 1,000,000	$ 1,000,000	$ 1,000,000
Weighted average grant date price per share (in dollars per share)	$ 78.00
2013 LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares of common stock that can be awarded under the plan	5,000,000
TSR Portion | Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%
Factor used for adjustment of Performance awards, low end (percent)	0.00%
Factor used for adjustment of Performance awards, high end (percent)	200.00%
Weighted average grant date price per share (in dollars per share)	$ 79.98
TSR Portion | Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date price per share (in dollars per share)	$ 79.70
Non-TSR Portion | Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Adjustment percentage used for Performance awards	50.00%
Factor used for adjustment of Performance awards, low end (percent)	0.00%
Factor used for adjustment of Performance awards, high end (percent)	200.00%
Weighted average grant date price per share (in dollars per share)	$ 90.48
Non-TSR Portion | Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date price per share (in dollars per share)	$ 89.65
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units issued (in shares)	33,200
Weighted average grant date price per share (in dollars per share)	$ 74.32
Stock Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares purchased on the open market	836,984	747,899	786,385
Weighted average share price per share, on shares purchased on open market (in dollars per share)	$ 79.82	$ 85.45	$ 78.27

XML

Stock-Based Compensation - Stock-Based Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 17	$ 47	$ 14
Income tax benefit	5	13	4
Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	7	36	3
Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	1	2	2
Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	3
Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	7	7	6
CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	16	40	13
Income tax benefit	4	11	4
CECONY | Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	6	30	3
CECONY | Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	1	2	1
CECONY | Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	3
CECONY | Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 7	$ 6	$ 6

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Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate, minimum	0.10%	1.58%	2.48%
Risk-free interest rate, maximum	0.13%	1.59%	2.63%
Expected term (years)	3 years	3 years	3 years
Expected share price volatility, minimum (percent)	30.16%	12.89%	14.76%
Expected share price volatility, maximum (percent)	40.95%	15.51%	17.71%

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Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2020 $ / shares shares
Units
Non-vested at beginning of period (in shares) | shares	991,238
Granted (in shares) | shares	329,600
Vested (in shares) | shares	(326,496)
Forfeited (in shares) | shares	(92,818)
Non-vested at end of period (in shares) | shares	901,524
CECONY
Units
Non-vested at beginning of period (in shares) | shares	742,204
Granted (in shares) | shares	249,761
Vested (in shares) | shares	(245,269)
Forfeited (in shares) | shares	(60,225)
Non-vested at end of period (in shares) | shares	686,471
TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 68.15
Granted (in dollars per share)	79.98
Vested (in dollars per share)	73.07
Forfeited (in dollars per share)	73.80
Non-vested at end of period (in dollars per share)	$ 70.11
Adjustment percentage used for Performance awards	50.00%
TSR Portion | CECONY
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 68.06
Granted (in dollars per share)	79.70
Vested (in dollars per share)	72.70
Forfeited (in dollars per share)	73.61
Non-vested at end of period (in dollars per share)	70.15
Non-TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	77.14
Granted (in dollars per share)	90.48
Vested (in dollars per share)	74.57
Forfeited (in dollars per share)	87.98
Non-vested at end of period (in dollars per share)	$ 81.83
Adjustment percentage used for Performance awards	50.00%
Non-TSR Portion | CECONY
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 77.32
Granted (in dollars per share)	89.65
Vested (in dollars per share)	74.76
Forfeited (in dollars per share)	87.73
Non-vested at end of period (in dollars per share)	$ 81.80

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Stock-Based Compensation - Summary of Changes in Status of Time-Based Awards (Details) - Time-based Awards	12 Months Ended
	Dec. 31, 2020 $ / shares shares
Units
Non-vested at beginning of period (in shares) | shares	67,250
Granted (in shares) | shares	22,450
Vested (in shares) | shares	(20,750)
Forfeited (in shares) | shares	(1,512)
Non-vested at end of period (in shares) | shares	67,438
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 80.36
Granted (in dollars per share) | $ / shares	78.00
Vested (in dollars per share) | $ / shares	77.66
Forfeited (in dollars per share) | $ / shares	80.30
Non-vested at end of period (in dollars per share) | $ / shares	$ 80.40
CECONY
Units
Non-vested at beginning of period (in shares) | shares	63,100
Granted (in shares) | shares	20,900
Vested (in shares) | shares	(19,650)
Forfeited (in shares) | shares	(1,512)
Non-vested at end of period (in shares) | shares	62,838
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 80.36
Granted (in dollars per share) | $ / shares	78.00
Vested (in dollars per share) | $ / shares	77.66
Forfeited (in dollars per share) | $ / shares	80.30
Non-vested at end of period (in dollars per share) | $ / shares	$ 80.42

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Financial Information by Business Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Revenues	$ 12,246	$ 12,574	$ 12,337	$ 12,033
Depreciation and amortization	1,920	1,684	1,438
Operating income	2,654	2,676	2,664
Other Income (deductions)	(401)	51	(62)
Interest charges	1,019	991	819
Income taxes on operating income	193	300	406
Total assets	62,895	58,079	53,920
Capital expenditures	4,085	3,676	5,249
Income tax expense (benefit) on non-operating income	(103)	(4)	(5)
Parent Company
Segment Reporting Information [Line Items]
Total assets	21,499	20,638
CECONY
Segment Reporting Information [Line Items]
Revenues	10,647	10,821	10,680
Depreciation and amortization	1,598	1,373	1,276
Operating income	2,310	2,348	2,354
Other Income (deductions)	(171)	(35)	(143)
Total assets	50,967	46,557
Income tax expense (benefit) on non-operating income	(3)	(7)	(2)
Operating segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	736	857	763
Depreciation and amortization	231	226	85
Operating income	215	202	194
Other Income (deductions)	4	5	33
Interest charges	196	186	63
Income taxes on operating income	(43)	(58)	19
Total assets	6,848	6,528	5,821
Capital expenditures	616	248	1,791
Operating segment | Con Edison Transmission
Segment Reporting Information [Line Items]
Revenues	4	4	4
Depreciation and amortization	1	1	1
Operating income	(8)	(6)	(7)
Other Income (deductions)	(215)	104	91
Interest charges	18	25	20
Income taxes on operating income	0	1	(1)
Total assets	1,348	1,618	1,425
Capital expenditures	3	205	248
Operating segment | CECONY
Segment Reporting Information [Line Items]
Revenues	10,647	10,821	10,680
Depreciation and amortization	1,598	1,373	1,276
Operating income	2,310	2,348	2,354
Other Income (deductions)	(171)	(35)	(143)
Interest charges	739	728	689
Income taxes on operating income	218	342	328
Total assets	50,967	46,557	43,108
Capital expenditures	3,246	3,020	3,005
Operating segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	8,103	8,062	7,971
Depreciation and amortization	1,214	1,053	984
Operating income	1,731	1,758	1,799
Other Income (deductions)	(134)	(28)	(110)
Interest charges	535	539	519
Income taxes on operating income	130	239	233
Total assets	35,673	32,988	31,012
Capital expenditures	2,080	1,851	1,861
Operating segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	2,036	2,132	2,078
Depreciation and amortization	294	231	205
Operating income	574	528	478
Other Income (deductions)	(25)	(4)	(23)
Interest charges	164	147	131
Income taxes on operating income	102	99	87
Total assets	12,678	11,090	9,710
Capital expenditures	1,044	1,078	1,050
Operating segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	508	627	631
Depreciation and amortization	90	89	87
Operating income	5	62	77
Other Income (deductions)	(12)	(3)	(10)
Interest charges	40	42	39
Income taxes on operating income	(14)	4	8
Total assets	2,616	2,479	2,386
Capital expenditures	122	91	94
Operating segment | O&R
Segment Reporting Information [Line Items]
Revenues	862	893	891
Depreciation and amortization	90	84	77
Operating income	147	139	132
Other Income (deductions)	(14)	(11)	(19)
Interest charges	41	41	39
Income taxes on operating income	21	21	21
Total assets	3,247	3,006	2,892
Capital expenditures	220	203	205
Operating segment | O&R | Electric
Segment Reporting Information [Line Items]
Revenues	629	634	642
Depreciation and amortization	65	60	56
Operating income	99	98	93
Other Income (deductions)	(10)	(7)	(14)
Interest charges	26	27	25
Income taxes on operating income	13	15	14
Total assets	2,097	2,130	2,036
Capital expenditures	159	142	138
Operating segment | O&R | Gas
Segment Reporting Information [Line Items]
Revenues	233	259	249
Depreciation and amortization	25	24	21
Operating income	48	41	39
Other Income (deductions)	(4)	(4)	(5)
Interest charges	15	14	14
Income taxes on operating income	8	6	7
Total assets	1,150	876	856
Capital expenditures	61	61	67
Other
Segment Reporting Information [Line Items]
Revenues	(3)	(1)	(1)
Depreciation and amortization	0	0	(1)
Operating income	(10)	(7)	(9)
Other Income (deductions)	(5)	(12)	(24)
Interest charges	25	11	8
Income taxes on operating income	(3)	(6)	39
Total assets	485	370	674
Capital expenditures	0	0	0
Other | O&R
Segment Reporting Information [Line Items]
Revenues	0	0	0
Depreciation and amortization	0	0	0
Operating income	0	0	0
Other Income (deductions)	0	0	0
Interest charges	0	0	0
Income taxes on operating income	0	0	0
Total assets	0	0	0
Capital expenditures	0	0	0
Inter-segment
Segment Reporting Information [Line Items]
Revenues	0	0	0
Inter-segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	0	0	0
Inter-segment | CECONY
Segment Reporting Information [Line Items]
Revenues	(99)	(94)	(98)
Inter-segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	18	17	16
Inter-segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	7	7	7
Inter-segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	$ 74	$ 70	$ 75

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Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	$ (366)	$ (183)
Gross Amounts Offset	3	17
Net Amounts of Assets/ (Liabilities)	(363)	(166)
Margin deposits	3	9
CECONY
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	(252)	(124)
Gross Amounts Offset	0	17
Net Amounts of Assets/ (Liabilities)	(252)	(107)
Margin deposits	3	8
Clean Energy Businesses | Interest Rate Swap
Net fair value derivative assets/(liabilities)
Notional amount	863	919
Fair Value of Derivative Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(225)	(140)
Gross Amounts Offset	(13)	17
Net Amounts of Assets/ (Liabilities)	(238)	(123)
Fair Value of Derivative Liabilities, Current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(24)	(7)
Fair Value of Derivative Liabilities, Current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(174)	(100)
Gross Amounts Offset	11	19
Net Amounts of Assets/ (Liabilities)	(163)	(81)
Fair Value of Derivative Liabilities, Non-current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(207)	(122)
Gross Amounts Offset	(33)	16
Net Amounts of Assets/ (Liabilities)	(240)	(106)
Fair Value of Derivative Liabilities, Non-current | Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(82)	(34)
Fair Value of Derivative Liabilities, Non-current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(114)	(80)
Gross Amounts Offset	9	16
Net Amounts of Assets/ (Liabilities)	(105)	(64)
Fair Value of Derivative Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(432)	(262)
Gross Amounts Offset	(46)	33
Net Amounts of Assets/ (Liabilities)	(478)	(229)
Fair Value of Derivative Liabilities | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(288)	(180)
Gross Amounts Offset	20	35
Net Amounts of Assets/ (Liabilities)	(268)	(145)
Fair Value of Derivative Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	44	60
Gross Amounts Offset	14	(3)
Net Amounts of Assets/ (Liabilities)	58	57
Fair Value of Derivative Assets, Current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	20	39
Gross Amounts Offset	(12)	(6)
Net Amounts of Assets/ (Liabilities)	8	33
Fair Value of Derivative Assets, Non-current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	22	19
Gross Amounts Offset	35	(13)
Net Amounts of Assets/ (Liabilities)	57	6
Fair Value of Derivative Assets, Non-current | Interest Rate Swap
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)		1
Fair Value of Derivative Assets, Non-current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	16	17
Gross Amounts Offset	(8)	(12)
Net Amounts of Assets/ (Liabilities)	8	5
Fair Value of Derivative Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	66	79
Gross Amounts Offset	49	(16)
Net Amounts of Assets/ (Liabilities)	115	63
Fair Value of Derivative Assets | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	36	56
Gross Amounts Offset	(20)	(18)
Net Amounts of Assets/ (Liabilities)	$ 16	$ 38

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Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (26)	$ 1
Total deferred gains/(losses)	(301)	(300)
Net deferred gains/(losses)	(327)	(299)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(63)	(12)
Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(2)	(2)
Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	7	25
Other operations and maintenance expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(3)	1
Other interest expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(65)	(36)
Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(26)	4
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	(3)
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(63)	(91)
Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(201)	(142)
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(37)	(67)
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(27)	4
Total deferred gains/(losses)	(277)	(272)
Net deferred gains/(losses)	(304)	(268)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(3)	1
CECONY | Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0
CECONY | Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0
CECONY | Other operations and maintenance expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(3)	1
CECONY | Other interest expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0
CECONY | Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(27)	5
CECONY | Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	0	(1)
CECONY | Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(64)	(83)
CECONY | Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(177)	(124)
CECONY | Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ (36)	$ (65)

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Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details)	Dec. 31, 2020 gal MMBTU MWh MW
Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	28,102,230
Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	47,258
Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	286,819,910
Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	7,728,000
CECONY | Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	26,193,800
CECONY | Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	35,400
CECONY | Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	267,380,000
CECONY | Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	7,728,000

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Derivative Instruments and Hedging Activities - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($)
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 217
Makeup of net credit exposure with investment-grade counterparties	47
Makeup of net credit exposure independent system operators	103
Makeup of net credit exposure with commodity exchange brokers	27
Makeup of net credit exposure non-investment grade/non-rated counterparties	40
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	16
Makeup of net credit exposure with commodity exchange brokers	$ 16

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Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Details) $ in Millions	Dec. 31, 2020 USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 293
Collateral posted	212
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	5
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	101
Derivatives in net asset position additional collateral	25
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	51
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	277
Collateral posted	200
CECONY | Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	0
CECONY | Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	$ 85

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Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ (19)
Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(10)
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Transfer out of level 3	1	$ 24
Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Transfer out of level 3	1	22
Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	675	550
Derivative liabilities	478	229
Recurring | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	550	498
Recurring | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	53	4
Derivative liabilities	46	(22)
Recurring | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(16)
Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	450	357
Derivative liabilities	7	18
Recurring | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	426	336
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	168	187
Derivative liabilities	402	215
Recurring | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	140	161
Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4	2
Derivative liabilities	23	18
Recurring | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	118	71
Derivative liabilities	372	188
Recurring | Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	19	46
Derivative liabilities	268	145
Recurring | Commodity | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	53	4
Derivative liabilities	46	(22)
Recurring | Commodity | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(16)
Derivative liabilities	(19)	(24)
Recurring | Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	19	4
Derivative liabilities	7	18
Recurring | Commodity | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	15	3
Derivative liabilities	3	15
Recurring | Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	42	61
Derivative liabilities	296	174
Recurring | Commodity | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	20	42
Derivative liabilities	274	147
Recurring | Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4	2
Derivative liabilities	23	18
Recurring | Commodity | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Derivative liabilities	10	7
Recurring | Interest Rate Swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Derivative liabilities	106	41
Recurring | Interest Rate Swaps | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Recurring | Interest Rate Swaps | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Recurring | Interest Rate Swaps | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Derivative liabilities	106	41
Recurring | Interest Rate Swaps | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Recurring | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	557	478
Recurring | Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	531	452
Recurring | Other | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Other | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	431	353
Recurring | Other | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	411	333
Recurring | Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	126	125
Recurring | Other | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	120	119
Recurring | Other | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Recurring | Other | Level 3 | CECONY
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) - Level 3 $ in Millions	Dec. 31, 2020 USD ($) $ / kW-month $ / MWh
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (19)
CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(10)
Electricity | Forward Capacity Prices
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	(20)
Electricity | Forward Capacity Prices | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ (11)
Electricity | Forward Capacity Prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	0.06
Electricity | Forward Capacity Prices | Minimum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	0.08
Electricity | Forward Capacity Prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	6.26
Electricity | Forward Capacity Prices | Maximum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / kW-month	6.26
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives	$ 1
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	(2.65)
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Minimum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	0.23
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	7.69
Transmission Congestion Contracts | Inter-Zonal Forward Price Curves | Maximum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per unit) | $ / MWh	1.13

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Fair Value Measurements - Reconciliation of Beginning and Ending Net Balances for Assets and Liabilities Measured at Level 3 Fair Value (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ (16)	$ (13)
Included in earnings	(10)	(5)
Included in regulatory assets and liabilities	(7)	18
Settlements	15	8
Transfer out of level 3	(1)	(24)
Ending Balance	(19)	(16)
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	(6)	(2)
Included in earnings	(5)	0
Included in regulatory assets and liabilities	(4)	17
Settlements	6	1
Transfer out of level 3	(1)	(22)
Ending Balance	$ (10)	$ (6)

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Fair Value Measurements - Additional Information (Details) - Clean Energy Businesses - Non-utility revenue - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Gain (loss) on Level 3 energy derivative assets and liabilities	$ 3	$ 2
Fair value, assets and liabilities measured on recurring basis, change in unrealized gain (loss)	$ 2	$ 2

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Variable Interest Entities - Additional Information (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2019 MW	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Variable Interest Entity [Line Items]
Noncontrolling interest		$ 218	$ 191
Texas Solar 4 | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Generating capacity (MW AC) | MW	40
Texas Solar 4 | Con Edison Development | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Percentage of variable interests (less than)	80.00%
Ownership percentage acquired		20.00%
Tax Equity Projects | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Income (loss)		$ (6)	(64)
Income (loss), after tax		$ (4)	(48)
Tax Equity Projects | Con Edison Development | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Percentage of variable interests (less than)		100.00%
Tax Equity Projects | Tax Equity Investors | Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Income (loss)		$ 44	98
Income (loss), after tax		$ 32	$ 74

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Variable Interest Entities - Net Assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Business Acquisition [Line Items]
Noncontrolling interest	$ 218	$ 191
Great Valley Solar
Business Acquisition [Line Items]
Non-utility property, less accumulated depreciation	284	293
Other assets	39	40
Total assets	323	333
Other liabilities	13	17
Total liabilities	13	17
Accumulated depreciation	18	9
Copper Mountain Solar - Mesquite Solar
Business Acquisition [Line Items]
Non-utility property, less accumulated depreciation	446	461
Other assets	176	128
Total assets	622	589
Other liabilities	71	18
Total liabilities	71	18
Accumulated depreciation	30	15
Tax Equity Investors | Great Valley Solar
Business Acquisition [Line Items]
Noncontrolling interest	82	62
Tax Equity Investors | Copper Mountain Solar - Mesquite Solar
Business Acquisition [Line Items]
Noncontrolling interest	$ 134	$ 126

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Variable Interest Entities - Summary of VIEs (Details) - Variable Interest Entity, Not Primary Beneficiary $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($) MW
Great Valley Solar
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	200
Maximum Exposure to Loss | $	$ 228
Great Valley Solar | Minimum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	15 years
Great Valley Solar | Maximum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	20 years
Copper Mountain Solar - Mesquite Solar
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW	344
Maximum Exposure to Loss | $	$ 417
Copper Mountain Solar - Mesquite Solar | Minimum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	20 years
Copper Mountain Solar - Mesquite Solar | Maximum
Variable Interest Entity [Line Items]
Power Purchase Agreement Term in Years	25 years

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Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	$ 576	$ 425
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	191	(1)
Asset retirement obligations, accretion expense	16	14
Asset retirement obligations, liabilities settled	56	38
Asset retirement obligations, reductions	49	44
CECONY
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	508	362
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	186	96
Asset retirement obligations, accretion expense	13	12
Asset retirement obligations, liabilities settled	53	38
Asset retirement obligations, reductions	$ 49	$ 44

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Related Party Transactions - Additional Information (Details) MMBTU in Thousands	12 Months Ended
	Dec. 31, 2020 USD ($) MMBTU	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)
Related Party Transaction [Line Items]
Net assets	$ 18,847,000,000	$ 18,022,000,000
CECONY
Related Party Transaction [Line Items]
Net assets	14,849,000,000	14,147,000,000	$ 12,910,000,000	$ 12,439,000,000
Sale of natural gas	59,000,000	71,000,000	83,000,000
Funding limit of CECONY to O&R (not to exceed)	$ 250,000,000
CECONY | Related Party, Lending of Funds
Related Party Transaction [Line Items]
Lending period (not more than) (months)	12 months
CECONY | Equity Method Investee | Mountain Valley Pipeline
Related Party Transaction [Line Items]
Amount of transaction	$ 0	0
Contract term (years)	20 years
Generating capacity per day (in dekatherms) | MMBTU	250
CECONY | Equity Method Investee | Stagecoach | Purchased Power Costs
Related Party Transaction [Line Items]
Amount of transaction	$ 34,000,000	33,000,000	$ 28,000,000
CECONY | Affiliated Entity | Financial Electric Capacity Contract | Con Edison Energy
Related Party Transaction [Line Items]
Gain (loss) on financial electric capacity contracts	(1,000,000)	(1,000,000)
O&R
Related Party Transaction [Line Items]
Net assets	807,000,000
Outstanding loans	$ 0	$ 0
CET Electric | NY Transco
Related Party Transaction [Line Items]
Ownership interest, percentage	45.70%
CET Gas | Mountain Valley Pipeline
Related Party Transaction [Line Items]
Percentage of equity interest owned	11.30%
Expected reduction in equity interest	8.80%

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Related Party Transactions - Summary of Costs of Administrative and Other Services Provided and Received (Details) - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Related Party Transaction [Line Items]
Cost of services provided	$ 128	$ 121	$ 115
Cost of services received	$ 66	$ 64	$ 73

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Acquisitions, Investments and Dispositions - Sempra Solar (Details) $ / shares in Units, $ in Millions		11 Months Ended	12 Months Ended
	Dec. 13, 2018 USD ($) $ / shares MW	Dec. 12, 2018 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2020 USD ($)
Business Acquisition [Line Items]
Business acquisition, pre-tax gain from interests in projects	$ 131			$ 131
Long-term debt			$ 19,973		$ 22,349
Sempra Solar
Business Acquisition [Line Items]
Ownership percentage	50.00%
Renewable Electric Production Projects | Sempra Solar
Business Acquisition [Line Items]
Project generating capacity (MW AC) | MW	379
Sempra Solar
Business Acquisition [Line Items]
Business acquisition, pre-tax gain from interests in projects	$ 131
Business acquisition, after-tax gain from interests in projects	$ 89
Business acquisition, after-tax gain from interests in projects, per share (in dollars per share) | $ / shares	$ 0.28
Con Edison Development | Sempra Solar
Business Acquisition [Line Items]
Purchase price	$ 1,609
Working capital and other closing adjustments	69
Reclassification adjustment to property, plant and equipment and asset retirement obligations			$ 100
Period available to finalize purchase price allocation			1 year
Acquisition-date fair value of ownership interest held	568	$ 437
Property, plant and equipment acquired	1,354
Intangible assets acquired	878
Noncurrent assets	$ 4
Weighted average amortization period for intangible assets	16 years
Fair value of noncontrolling interest attributable to tax equity investors	$ 100
Sempra Solar | Renewable Electric Production Projects
Business Acquisition [Line Items]
Project generating capacity (MW AC) | MW	981
Long-term debt	$ 568
Asset retirement obligation	$ 28

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Acquisitions, Investments and Dispositions - Pro Forma Supplemental Information (Details) - USD ($) $ in Millions		12 Months Ended
	Dec. 13, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 01, 2017
Business Combinations [Abstract]
Revenues		$ 12,246	$ 12,574	$ 12,337	$ 12,033
Net income		$ 1,101	$ 1,343	1,382	1,525
If Acquired January 1, 2017 (a)(b)
Revenue				12,655	12,331
Net income				1,279	1,612
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Interest expense				37	38
Business acquisition, pre-tax gain from interests in projects	$ 131				131
Pro Forma
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Income from equity method investment				33	$ 32
Term Loan
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Short-term borrowings				$ 825
Fixed interest rate						4.64%

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Schedule I - Condensed Financial Information - Income and Comprehensive Income (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Income Statements,Captions [Line Items]
Interest expense	$ (1,019)	$ (991)	$ (819)
NET INCOME FOR COMMON STOCK	1,101	1,343	1,382	$ 1,525
Comprehensive Income	$ 1,095	$ 1,340	$ 1,392
Net Income Per Share – Basic (in dollars per share)	$ 3.29	$ 4.09	$ 4.43
Net Income Per Share – Diluted (in dollars per share)	$ 3.28	$ 4.08	$ 4.42
Average Number Of Shares Outstanding—Basic (in shares)	334.8	328.5	311.7
Average Number Of Shares Outstanding—Diluted (in shares)	335.7	329.5	312.9
Parent Company
Condensed Income Statements,Captions [Line Items]
Equity in earnings of subsidiaries	$ 1,105	$ 1,354	$ 1,447
Other income (deductions), net of taxes	56	76	(6)
Interest expense	(60)	(87)	(59)
NET INCOME FOR COMMON STOCK	1,101	1,343	1,382
Comprehensive Income	$ 1,095	$ 1,340	$ 1,392
Net Income Per Share – Basic (in dollars per share)	$ 3.29	$ 4.09	$ 4.43
Net Income Per Share – Diluted (in dollars per share)	3.28	4.08	4.42
Dividends Declared Per Share (in dollars per share)	$ 3.06	$ 2.96	$ 2.86
Average Number Of Shares Outstanding—Basic (in shares)	334.8	328.5	311.1
Average Number Of Shares Outstanding—Diluted (in shares)	335.7	329.5	312.9

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Schedule I - Condensed Financial Information - Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	$ 1,101	$ 1,343	$ 1,382	$ 1,525
Change in Assets:
Taxes receivable	(6)	29	27
Other – net	(134)	54	(62)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,198	3,134	2,695
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,224)	(3,782)	(5,471)
FINANCING ACTIVITIES
Net proceeds of short-term debt	178	(874)	1,989
Issuance of long-term debt	2,925	3,017	3,030
Retirement of long-term debt	(518)	(1,195)	(1,938)
Debt issuance costs	(47)	(32)	(61)
Issuance of common shares for stock plans	58	54	53
Issuance of common shares - public offering	640	825	705
Common stock dividends	(975)	(924)	(842)
NET CASH FLOWS FROM FINANCING ACTIVITIES	2,245	859	2,938
NET CHANGE FOR THE PERIOD	219	211	162
BALANCE AT BEGINNING OF PERIOD	1,217	1,006	844
BALANCE AT END OF PERIOD	1,436	1,217	1,006	844
CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,185	1,250	1,196
Change in Assets:
Other – net	(49)	54	(96)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,693	2,502	2,204
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(3,416)	(3,124)	(3,306)
FINANCING ACTIVITIES
Net proceeds of short-term debt	523	(55)	1,042
Issuance of long-term debt	2,200	1,300	2,740
Retirement of long-term debt	(350)	(475)	(1,836)
Debt issuance costs	(34)	(21)	(30)
NET CASH FLOWS FROM FINANCING ACTIVITIES	1,857	737	1,190
NET CHANGE FOR THE PERIOD	134	115	88
BALANCE AT BEGINNING OF PERIOD	933	818	730
BALANCE AT END OF PERIOD	1,067	933	818	730
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,101	1,343	1,382
Equity in earnings of subsidiaries	(1,105)	(1,354)	(1,447)
Change in Assets:
Special deposits	0	(3)	(8)
Taxes receivable		25	2
Other – net	654	44	187
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,713	1,029	1,033
INVESTING ACTIVITIES
Contributions to subsidiaries	(626)	(930)	(1,110)
Debt receivable from affiliated companies	400	450	(825)
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(226)	(480)	(1,935)
FINANCING ACTIVITIES
Net proceeds of short-term debt	(537)	(783)	164
Issuance of long-term debt	650	825	825
Retirement of long-term debt	(1,178)	(553)	(3)
Debt issuance costs	(3)	0	0
Issuance of common shares for stock plans	58	54	53
Issuance of common shares - public offering	640	825	705
Common stock dividends	(975)	(924)	(842)
NET CASH FLOWS FROM FINANCING ACTIVITIES	(1,345)	(556)	902
NET CHANGE FOR THE PERIOD	142	(7)	0
BALANCE AT BEGINNING OF PERIOD	2	9	9
BALANCE AT END OF PERIOD	144	2	9	$ 9
Parent Company | CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	982	912	846
Parent Company | O&R
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	49	47	46
Parent Company | Clean Energy Businesses
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	21	3	15
Parent Company | Con Edison Transmission
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	$ 11	$ 12	$ 10

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Schedule I - Condensed Financial Information - Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Current Assets
Cash and temporary cash investments	$ 1,272	$ 981
Accounts receivable - customers, less allowance for uncollectible accounts	1,701	1,236
Taxes receivable	26	20
Prepayments	271	260
Other current assets	231	200
TOTAL CURRENT ASSETS	5,301	4,272
Investments in subsidiaries and others	1,816	2,065
Goodwill	446	446
Other noncurrent assets	9,223	7,853
TOTAL ASSETS	62,895	58,079	$ 53,920
Current Liabilities
Long-term debt due within one year		1,446
Term Loan	165	0
Notes payable	1,705	1,692
Accounts payable	1,475	1,164
Accrued taxes	150	76
Other current liabilities	426	371
TOTAL CURRENT LIABILITIES	7,354	6,287
Long-term debt	20,382	18,527
Shareholders’ Equity
Equity	18,847	18,022
TOTAL LIABILITIES AND EQUITY	62,895	58,079
Parent Company
Current Assets
Cash and temporary cash investments	144	2
Accounts receivable - customers, less allowance for uncollectible accounts	1
Taxes receivable	18	18
Term loan receivable from affiliated companies	0	0
Accounts receivable from affiliated companies	1,256	870
Prepayments	62	32
Other current assets	12	12
TOTAL CURRENT ASSETS	1,493	934
Investments in subsidiaries and others	18,670	18,009
Goodwill	406	406
Deferred income tax	55	14
Long-term debt receivable from affiliated companies	875	1,275
Other noncurrent assets	0	0
TOTAL ASSETS	21,499	20,638
Current Liabilities
Long-term debt due within one year	1,178	3
Term Loan	0	0
Notes payable	0	537
Accounts payable	0	0
Accounts payable to affiliated companies	517	595
Accrued taxes	6	2
Other current liabilities	12	10
TOTAL CURRENT LIABILITIES	1,713	1,147
Deferred income tax	0	0
Total Liabilities	1,713	1,147
Long-term debt	939	1,469
Shareholders’ Equity
Common stock, including additional paid-in capital	8,844	8,089
Retained earnings	10,003	9,933
Equity	18,847	18,022
TOTAL LIABILITIES AND EQUITY	$ 21,499	$ 20,638

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Schedule II - Valuation and Qualifying Accounts (Details) - Allowance For Uncollectible Accounts - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 74	$ 68	$ 70
Charged To Costs And Expenses	72	77	62
Charged To Other Accounts	0	0	0
Deductions	8	(71)	(64)
Balance At End of Period	154	74	68
CECONY
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	68	61	65
Charged To Costs And Expenses	65	72	56
Charged To Other Accounts	0	0	0
Deductions	10	(65)	(60)
Balance At End of Period	$ 143	$ 68	$ 61