10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

___________________________________________________ 

FORM 10-K

___________________________________________________  

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

FOR THE FISCAL YEAR ENDED DECEMBER 31, 2016

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

 ___________________________________________________  

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

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

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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).

Con Edison	Yes	x	No	¨
CECONY	Yes	x	No	¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ¨

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

Con Edison
Large accelerated filer	x	Accelerated filer	¨	Non-accelerated filer	¨	Smaller reporting company	¨
CECONY
Large accelerated filer	¨	Accelerated filer	¨	Non-accelerated filer	x	Smaller reporting company	¨

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, 2016, was approximately $24.5 billion.

As of January 31, 2017, Con Edison had outstanding 305,059,148 Common Shares ($.10 par value).

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 15, 2017, to be filed with the Commission pursuant to Regulation 14A, not later than 120 days after December 31, 2016, is incorporated in Part III of this report.

2

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.

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
Con Edison Development	Consolidated Edison Development, Inc.
Con Edison Energy	Consolidated Edison Energy, Inc.
Con Edison Solutions	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.
Pike	Pike County Light & Power Company
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
ASU	Accounting Standards Update
GAAP	Generally Accepted Accounting Principles in the United States of America
LILO	Lease In/Lease Out
OCI	Other Comprehensive Income
VIE	Variable Interest Entity

4

Environmental
CO2	Carbon dioxide
GHG	Greenhouse gases
MGP Sites	Manufactured gas plant sites
PCBs	Polychlorinated biphenyls
PRP	Potentially responsible party
RGGI	Regional Greenhouse Gas Initiative
Superfund	Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes
Units of Measure
AC	Alternating current
Bcf	Billion cubic feet
Dt	Dekatherms
kV	Kilovolt
kWh	Kilowatt-hour
MDt	Thousand dekatherms
MMlb	Million pounds
MVA	Megavolt ampere
MW	Megawatt or thousand kilowatts
MWh	Megawatt hour
Other
AFUDC	Allowance for funds used during construction
AMI	Advanced metering infrastructure
COSO	Committee of Sponsoring Organizations of the Treadway Commission
DER	Distributed energy resources
EGWP	Employer Group Waiver Plan
Fitch	Fitch Ratings
LTIP	Long Term Incentive Plan
Moody’s	Moody’s Investors Service
REV	Reforming the Energy Vision
S&P	Standard & Poor’s Financial Services LLC
VaR	Value-at-Risk

5

TABLE OF CONTENTS

		PAGE
Introduction		7
Available Information		9
Forward-Looking Statements		9
Non-GAAP Financial Measure		10
Part I
Item 1:	Business	13
Item 1A:	Risk Factors	38
Item 1B:	Unresolved Staff Comments	41
Item 2:	Properties	41
Item 3:	Legal Proceedings	42
Item 4:	Mine Safety Disclosures	42
	Executive Officers of the Registrant	42
Part II
Item 5:	Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	44
Item 6:	Selected Financial Data	45
Item 7:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	46
Item 7A:	Quantitative and Qualitative Disclosures about Market Risk	74
Item 8:	Financial Statements and Supplementary Data	75
Item 9:	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	156
Item 9A:	Controls and Procedures	156
Item 9B:	Other Information	156
Part III
Item 10:	Directors, Executive Officers and Corporate Governance	157
Item 11:	Executive Compensation	157
Item 12:	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	157
Item 13:	Certain Relationships and Related Transactions, and Director Independence	157
Item 14:	Principal Accounting Fees and Services	157
Part IV
Item 15:	Exhibits and Financial Statement Schedules	159
Item 16:	Form 10-K Summary	164
	Signatures	165

6

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 an environmentally sound manner; to provide a workplace that 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.

Con Edison is a holding company that owns:

• Consolidated Edison Company of New York, Inc. (CECONY), which delivers electricity, natural gas and steam to customers in New York City and Westchester County;

• Orange & Rockland Utilities, Inc. (O&R), which together with its subsidiary, Rockland Electric Company, delivers electricity and natural gas to customers primarily located in southeastern New York State and northern New Jersey (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 energy infrastructure projects and provide 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 and gas transmission projects (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 electricity 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.

Selected Financial Data

Con Edison

	For the Year Ended December 31,
(Millions of Dollars, except per share amounts)	2012	2013		2014		2015		2016
Operating revenues	$12,188	$12,354		$12,919		$12,554		$12,075
Energy costs	3,887	4,054		4,513		3,716		3,088
Operating income	2,339	2,244		2,209		2,427		2,575
Net income	1,141	1,062	(a)	1,092		1,193		1,245
Total assets (f)(g)	40,845	40,451	(b)	44,071	(c)	45,642	(d)	48,255	(e)
Long-term debt (f)	9,994	10,415		11,546		12,006		14,735
Total equity	11,869	12,245		12,585		13,061		14,306
Net Income per common share – basic	$3.88	$3.62		$3.73		$4.07		$4.15
Net Income per common share – diluted	$3.86	$3.61		$3.71		$4.05		$4.12
Dividends declared per common share	$2.42	$2.46		$2.52		$2.60		$2.68
Book value per share	$40.53	$41.81		$42.97		$44.50		$46.91
Average common shares outstanding (millions)	293	293		293		293		300
Stock price low	$53.63	$54.33		$52.23		$56.86		$63.47
Stock price high	$65.98	$63.66		$68.92		$72.25		$81.88

(a) Reflects a charge to earnings of $95 million (after taxes of $63 million) relating to the lease in/lease out (LILO) transactions that were terminated in 2013.

(b) Reflects a $2,947 million decrease in regulatory assets for unrecognized pension and other postretirement costs offset by an increase of $1,497 million, $280 million, $257 million and $223 million in net plant, cash, special deposits and regulatory assets for future income tax, respectively.

(c) Reflects a $2,116 million increase in regulatory assets for unrecognized pension and other postretirement costs and a $1,391 million increase in net plant. See Notes B, E and F to the financial statements in Item 8.

(d) Reflects a $2,382 million increase in net plant offset by a $970 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.

7

(e) Reflects a $3,007 million increase in net plant offset by a $1,002 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.

(f) Reflects $68 million, $74 million and $85 million in 2012, 2013 and 2014, respectively, related to the adoption of Accounting Standards Update (ASU) No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs.”

(g) Reflects $296 million, $122 million and $152 million in 2012, 2013, 2014, respectively, related to the adoption of ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes.”

CECONY

	For the Year Ended December 31,
(Millions of Dollars)	2012	2013		2014		2015		2016
Operating revenues	$10,187	$10,430		$10,786		$10,328		$10,165
Energy costs	2,665	2,873		2,985		2,304		2,059
Operating income	2,093	2,060		2,139		2,247		2,262
Net income	1,014	1,020		1,058		1,084		1,056
Total assets (e)(f)	36,630	36,095	(a)	39,443	(b)	40,230	(c)	40,856	(d)
Long-term debt (e)	9,083	9,303		10,788		10,787		12,073
Shareholder’s equity	10,552	10,847		11,188		11,415		11,829

(a) Reflects a $2,797 million decrease in regulatory assets for unrecognized pension and other postretirement costs offset by an increase of $1,405 million, $280 million, $215 million and $199 million in net plant, cash, regulatory assets for environmental remediation costs and regulatory assets for future income tax, respectively.

(b) Reflects a $1,999 million increase in regulatory assets for unrecognized pension and other postretirement costs and a $1,440 million increase in net plant. See Notes B, E and F to the financial statements in Item 8.

(c) Reflects a $1,725 million increase in net plant and a $912 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.

(d) Reflects a $1,804 million increase in net plant and a $967 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.

(e) Reflects $62 million, $63 million and $76 million in 2012, 2013 and 2014, respectively, related to the adoption of ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs.”

(f) Reflects $193 million, $100 million and $118 million in 2012, 2013 and 2014, respectively, related to the adoption of ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes.”

Significant 2016 Developments and Outlook

• Con Edison reported 2016 net income of $1,245 million or $4.15 a share compared with $1,193 million or $4.07 a share in 2015. Adjusted earnings were $1,198 million or $3.99 a share in 2016 compared with $1,196 million or $4.08 a share in 2015. See “Results of Operations” in Item 7 and “Non-GAAP Financial Measure” below.

• In 2016, the Utilities invested $2,922 million to upgrade and reinforce their energy delivery systems, Con Edison Transmission invested $1,078 million in electric transmission and gas pipeline and storage businesses and the Clean Energy Businesses invested $1,235 million primarily in renewable electric production projects. See "Capital Requirements and Resources" in Item 1 and Note U to the financial statements in Item 8.

• In 2017, the Utilities expect to invest $3,154 million for their energy delivery systems, Con Edison Transmission expects to invest $90 million in gas pipeline and storage businesses and the Clean Energy Businesses expect to invest $450 million in renewable electric production projects. Con Edison plans to meet its 2017 capital requirements through internally-generated funds and the issuance of securities. The company’s plans include the issuance of between $1,000 million and $1,800 million of long-term debt, most of which would be at the Utilities, and the issuance of additional debt secured by its renewable electric production projects. The company’s plans also include the issuance of up to $350 million of common equity in addition to equity under its dividend reinvestment, employee stock purchase and long term incentive plans. See “Capital Requirements and Resources” in Item 1.

• In 2016, the Clean Energy Businesses sold their retail electric supply business and O&R sold its Pennsylvania utility subsidiary for aggregate cash consideration of $250 million. See Note U to the financial statements in Item 8.

• CECONY forecasts average annual growth in peak demand in its service area at design conditions over the next five years for electric and gas to be approximately 0.2 percent and 2.3 percent, respectively, and average annual decrease in steam peak demand in its service area at design conditions over the next five years to be approximately 0.7 percent. O&R forecasts average annual decrease in electric peak demand in its service area at design conditions over the next five years to be approximately 0.1 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.

8

• In 2016, the New York State Public Service Commission (NYSPSC) continued its Reforming the Energy Vision (REV) proceeding to improve system efficiency and reliability, encourage renewable energy and distributed energy resources and empower customer choice. The NYSPSC, among other things, issued orders adopting a ratemaking and utility revenue framework and a clean energy standard and an order approving CECONY’s advanced metering infrastructure (AMI) plan for the company’s electric and gas businesses. See “Utility Regulation - State Utility Regulation - Reforming the Energy Vision” in Item 1.

• In 2016, the NYSPSC continued its proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities and its review of a March 2014 explosion and fire in which eight people died and more than 50 people were injured. In February 2017, the NYSPSC approved a settlement agreement with CECONY related to these matters. Pursuant to the settlement agreement, the company will not recover from customers $126 million of costs it incurred for gas emergency response activities in 2014, 2015 and 2016 in excess of amounts reflected in its gas rate plan for those years. At December 31, 2016, the company had not deferred any such incremental costs as a regulatory asset. In addition, the company will provide $27 million of future benefits to customers. At December 31, 2016, the company had accrued a regulatory liability for these future benefits. See “Other Regulatory Matters” in Note B and “Manhattan Explosion and Fire” in Note H to the financial statements in Item 8.

• In January 2017, the NYSPSC approved a September 2016 Joint Proposal among CECONY, the NYSPSC staff and other parties for CECONY electric and gas rate plans for the three-year period January 2017 through December 2019. See “Rate Plans” in Note B to the financial statements in Item 8.

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 public may read and copy any materials that the Companies file with the SEC at the SEC’s Public Reference Room at 100 F Street, N.E., Room 1580 Washington, D.C. 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. 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, Management Development and Compensation Committee, and Corporate Governance and Nominating 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.

Information on the Companies’ websites is not incorporated herein.

Forward-Looking Statements

This report includes forward-looking statements intended to qualify for the safe-harbor provisions of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements are statements of future expectation and not facts. Words such as “forecasts,” “expects,” “estimates,” “anticipates,” “intends,” “believes,” “plans,” “will” and similar expressions identify forward-looking statements. Forward-looking statements are based on information available at the time the statements are made, and accordingly speak only as of that time. Actual results or developments might differ materially from those included in the forward-looking statements because of various factors including, but not limited to, those discussed under “Risk Factors,” in Item 1A.

9

Non-GAAP Financial Measure

Adjusted earnings is a financial measure that is not determined in accordance with generally accepted accounting principles in the United States of America (GAAP). This non-GAAP financial measure should not be considered as an alternative to net income, which is an indicator of financial performance determined in accordance with GAAP. Adjusted earnings excludes from net income the net mark-to-market changes in the fair value of the derivative instruments the Clean Energy Businesses use to economically hedge market price fluctuations in related underlying physical transactions for the purchase or sale of electricity and gas. Adjusted earnings may also exclude from net income certain other items that the company does not consider indicative of its ongoing financial performance. Management uses this non-GAAP financial measure to facilitate the analysis of the company's financial performance as compared to its internal budgets and previous financial results. Management also uses this non-GAAP financial measure to communicate to investors and others the company’s expectations regarding its future earnings and dividends on its common stock. Management believes that this non-GAAP financial measure also is 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 to adjusted earnings and reported earnings per share to adjusted earnings per share.

(Millions of Dollars, except per share amounts)	2012	2013	2014	2015	2016
Reported net income – GAAP basis	$1,138	$1,062	$1,092	$1,193	$1,245
Gain on sale of the Clean Energy Businesses' retail electric supply business (a)	—	—	—	—	(56)
Goodwill impairment related to the Clean Energy Businesses' energy service business (b)	—	—	—	—	12
Impairment of assets held for sale (c)	—	—	—	3	—
Gain on sale of solar electric production projects (d)	—	—	(26)	—	—
Loss from LILO transactions (e)	—	95	1	—	—
Net mark-to-market effects of the Clean Energy Businesses (f)	(40)	(45)	73	—	(3)
Adjusted earnings	$1,098	$1,112	$1,140	$1,196	$1,198
Reported earnings per share – GAAP basis (basic)	$3.88	$3.62	$3.73	$4.07	$4.15
Gain on sale of the Clean Energy Businesses' retail electric supply business	—	—	—	—	(0.19)
Goodwill impairment related to the Clean Energy Businesses' energy service business	—	—	—	—	0.04
Impairment of assets held for sale	—	—	—	0.01	—
Gain on sale of solar electric production projects	—	—	(0.09)	—	—
Loss from LILO transactions	—	0.32	—	—	—
Net mark-to-market effects of the Clean Energy Businesses	(0.13)	(0.14)	0.25	—	(0.01)
Adjusted earnings per share	$3.75	$3.80	$3.89	$4.08	$3.99

(a) After taxes of $(48) million, which includes an adjustment for the apportionment of state income taxes. See Note U to the financial statements in Item 8.

(b) After taxes of $3 million. See Note K to the financial statements in Item 8.

(c) After taxes of $2 million, recorded related to Pike County Light & Power Company, which O&R sold in 2016. See Note U to the financial statements in Item 8.

(d) After taxes of $(19) million.

(e) In 2013, a court disallowed tax losses claimed by Con Edison relating to Con Edison Development’s Lease In/Lease Out (LILO) transactions and the company subsequently terminated the transactions, resulting in a charge to earnings of $95 million (after taxes of $63 million). In 2014, adjustments were made to taxes and accrued interest.

(f) After taxes of $(29) million, $(30) million and $55 million for the years ended December 31, 2012 through 2014. After taxes of $(2) million for the year ended December 31, 2016.

10

Item 1:    Business

Contents of Item 1	Page
Overview	13
CECONY	13
Electric	13
Gas	13
Steam	13
O&R	14
Electric	14
Gas	14
Sale of Pike County Light & Power Company (Pike)	14
Clean Energy Businesses	14
Sale of the Retail Electric Supply Business	14
Con Edison Transmission	14
Utility Regulation	14
State Utility Regulation	14
Regulators	14
New York Utility Industry	15
Rate Plans	17
Liability for Service Interruptions	17
Generic Proceedings	18
Federal Utility Regulation	18
New York Independent System Operator (NYISO)	18
Competition	19
The Utilities	19
CECONY	19
Electric Operations	19
Electric Facilities	19
Electric Sales and Deliveries	20
Electric Peak Demand	20
Electric Supply	21
Gas Operations	22
Gas Facilities	22
Gas Sales and Deliveries	22
Gas Peak Demand	23
Gas Supply	23
Steam Operations	23
Steam Facilities	23
Steam Sales and Deliveries	23
Steam Peak Demand and Capacity	24
Steam Supply	24
O&R	24
Electric Operations	24
Electric Facilities	24
Electric Sales and Deliveries	24
Electric Peak Demand	25
Electric Supply	25
Gas Operations	25
Gas Facilities	25
Gas Sales and Deliveries	26
Gas Peak Demand	26
Gas Supply	27

11

Contents of Item 1	Page
Clean Energy Businesses	27
Con Edison Development	27
Con Edison Energy	28
Con Edison Solutions	28
Con Edison Transmission	28
CET Electric	28
CET Gas	29
Capital Requirements and Resources	29
Environmental Matters	33
Climate Change	33
Environmental Sustainability	35
CECONY	35
O&R	37
Other Federal, State and Local Environmental Provisions	38
State Anti-Takeover Law	38
Employees	38

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.

12

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’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 energy infrastructure projects and provide energy-related products and services to wholesale and retail customers. Con Edison Transmission invests in electric transmission facilities and gas pipeline and storage facilities.

Con Edison seeks to provide shareholder value through continued dividend growth, supported by earnings growth in regulated utilities and contracted assets. The company invests to provide reliable, resilient, safe and clean energy critical for New York City’s growing economy. 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 3.4 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 19,979 MMlb of steam annually to approximately 1,649 customers in parts of Manhattan.

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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.

Sale of Pike County Light & Power Company (Pike)

In August 2016, O&R sold its Pennsylvania subsidiary, Pike, to Corning Natural Gas Holding Corporation (see Note U to the financial statements in Item 8).

Clean Energy Businesses

Con Edison formed Con Edison Clean Energy Businesses, Inc. and, in December 2016, transferred to it three wholly-owned subsidiaries: Consolidated Edison Development, Inc. (Con Edison Development), Consolidated Edison Energy, Inc. (Con Edison Energy) and Consolidated Edison Solutions, Inc. (Con Edison Solutions). Con Edison Clean Energy Businesses, Inc., together with these subsidiaries (which were formerly referred to as the competitive energy businesses), are referred to in this report as the Clean Energy Businesses.

Sale of the Retail Electric Supply Business

In September 2016, Con Edison sold the retail electric supply business of its Clean Energy Businesses to a subsidiary of Exelon Corporation (see Note U to the financial statements in Item 8).

Con Edison Transmission

Con Edison Transmission, Inc. invests in electric and gas transmission projects through its wholly-owned subsidiaries, Consolidated Edison Transmission, LLC (CET Electric) and Con Edison Gas Pipeline and Storage, LLC (CET Gas, which was formerly named Con Edison Gas Midstream, LLC). CET Electric, which was formed in 2014, is investing in a company that owns electric transmission assets in New York. CET Gas, which was formed in 2016, owns, through a subsidiary, a 50 percent equity interest in a joint venture that owns, operates and will further develop an existing gas pipeline and storage business located in northern Pennsylvania and southern New York. In addition, CET Gas owns a 12.5 percent equity interest in a company developing a proposed gas transmission project in West Virginia and Virginia. See “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, which 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. See “Capital Resources,” below. The NYSPSC exercises jurisdiction over the siting of the Utilities’ electric transmission lines (see “Con Edison Transmission,” below) and approves mergers or other business combinations involving New York utilities. In addition, the NYSPSC has the authority to impose penalties on utilities, which could be substantial, for violating state utility laws and regulations and its orders. See “Other Regulatory Matters” in Note B to the financial statements in Item 8. O&R’s New Jersey subsidiary, RECO, is subject to similar regulation by the New Jersey Board of Public Utilities (NJBPU). The NYSPSC, together with the NJBPU, are referred to herein as state utility regulators.

In March 2013, following the issuance of recommendations by a commission established by the Governor of New York and submission by the Governor of a bill to the State legislature, the New York Public Service Law was amended to, among other things, authorize the NYSPSC to (i) levy expanded penalties against combination gas and electric utilities; (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

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factors, including public interest and standards deemed necessary by the NYSPSC to ensure continuity of service, and due process).

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 2016, 65 percent of the electricity and 29 percent of the gas CECONY delivered to its customers, and 59 percent of the electricity and 42 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 four investor-owned utility companies – Con Edison, National Grid plc, Avangrid, Inc. (an affiliate of Iberdrola, S.A.) and Fortis Inc. – or one of two state authorities – New York Power Authority (NYPA) or Long Island Power Authority.

Reforming the Energy Vision

In April 2014, the NYSPSC instituted its REV proceeding, the goals of which are to improve electric system efficiency and reliability, encourage renewable energy resources, support distributed energy resources (DER) and empower customer choice. In this proceeding, the NYSPSC is examining the establishment of a distributed system platform to manage and coordinate DER, and provide customers with market data and tools to manage their energy use. The NYSPSC also is examining how its regulatory practices should be modified to incent utility practices to promote REV objectives.

In February 2015, the NYSPSC issued an order in its REV proceeding in which, among other things, the NYSPSC:

• ordered CECONY, O&R and the other electric utilities to file distributed system implementation plans (DSIPs) pursuant to which the utilities, under the NYSPSC’s authority and supervision, would serve as distributed system platforms to optimize the use of DER;

• indicated that the utilities will be allowed to own DER only under limited circumstances, and that utility affiliate ownership of DER within the utility’s service territory will require market power protections;

• ordered the utilities to file energy efficiency plans (see “Environmental Matters - Climate Change," below);

• instituted a separate proceeding to consider large-scale renewable generation;

• required the utilities to file demonstration projects for approval by NYSPSC staff; and

• indicated that the design and implementation of the reformed energy system will occur over a period of years.

In June 2015, the New York State Energy Research and Development Authority (NYSERDA) submitted a report in the large-scale renewable generation proceeding. The report included program design principles and strategies. The NYSPSC requested comments on, among other things: customer funding mechanisms; utility-backed power purchase agreements; financing options; and utility-owned generation. In December 2015, the Governor of New York directed the NYSPSC to establish a clean energy standard to mandate achievement by 2030 of the State Energy Plan’s goals of 50 percent of the State’s electricity being provided from renewable resources and reducing carbon emissions by 40 percent (see “Environmental Matters - Climate Change,” below) and to support the continued operation of upstate nuclear plants. In August 2016, the NYSPSC issued an order adopting a clean energy standard that includes renewable energy credit (REC) and zero-emissions credit (ZEC) requirements. Beginning in 2017, load serving entities (LSEs), including CECONY and O&R for their full-service customers, will be required to obtain RECs and ZECs in amounts determined by the NYSPSC. LSEs may satisfy their REC obligation by either purchasing RECs acquired through central procurement by NYSERDA, by self-supply through direct purchase of tradable RECs, or by making alternative compliance payments. LSEs will purchase ZECs from NYSERDA at prices determined by the NYSPSC. The order establishes an annual NYSPSC staff review and triennial NYSPSC review of the clean energy standard. Citing the risks that utility-backed power purchase agreements could impose on customers and utilities, the August 2016 order rejected requiring utilities to sign such agreements. The August 2016 order also did not authorize utility-owned renewable generation, stating a concern that allowing utilities to own renewable generation could result in reduced competition and higher costs.

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In July 2015, the NYSPSC staff issued a white paper on ratemaking and utility business models in the REV proceeding. The NYSPSC staff indicated that the proposals included in the white paper reflect the following foundational principles: align earning opportunities with customer value; maintain flexibility; provide accurate and appropriate value signals; maintain a sound electric industry; shift balance of regulatory incentives to market incentives; and achieve public policy objectives. In May 2016, the NYSPSC issued an order adopting a ratemaking and utility revenue framework. The order indicated that utilities will have four ways of achieving earnings: traditional cost-of-service earnings; earnings tied to achievement of alternatives that reduce utility capital spending and provide definitive consumer benefit; earnings from market-facing platform activities; and earnings from transitional outcome-based performance measures. The order also indicated, among other things, that existing measures for negative revenue adjustments for utility failure to meet basic service standards should generally be retained and net utility plant reconciliations should be modified to encourage cost-effective DER as an alternative to utility capital investment. The order directed each utility to file a system efficiency proposal; an interconnection survey process and proposed earnings adjustment mechanism; a progress report on aggregated data reporting automation; an aggregated data privacy policy statement; revisions to standby service tariffs and cost allocation matrix; one or more smart home rate demonstration proposals; and revisions to voluntary time of use rates and promotion and education tools.

In November 2015, CECONY submitted to the NYSPSC an update to the company’s advanced metering infrastructure (AMI) plan for its electric and gas delivery businesses. The plan addresses AMI’s financial, operational and environmental benefits to customers and how AMI supports the REV proceeding’s objectives. In March 2016, the NYSPSC issued an order approving CECONY’s AMI plan, subject to a cap on capital expenditures of $1,285 million. AMI components include smart meters, a communication network, information technology systems and business applications. The plan provides for full deployment of AMI to CECONY’s customers to be implemented over a six-year period. During 2016, CECONY, at the NYSPSC’s direction, submitted a customer engagement plan, an update to the company’s benefit cost analysis and metrics that the NYSPSC can use to monitor the success of the project. O&R’s electric and gas rate plans authorize aggregate capital expenditures of approximately $24 million to begin AMI implementation for the company’s customers. In February 2017, O&R submitted to the NYSPSC a request to expend an additional approximately $74 million to expand the scope of the company’s AMI implementation to all of its New York customers.

In December 2015, the NYSPSC authorized a cost recovery surcharge mechanism for REV demonstration projects. Three CECONY and one O&R demonstration projects have been approved by the NYSPSC staff. The demonstration projects are expected to inform decisions with respect to developing distributed system platform functionalities, measuring customer response to programs and prices associated with REV markets.

In January 2016, the NYSPSC established a benefit cost analysis framework that will apply to, among other things, utility proposals to make investments that could instead be met through DER alternatives that meet all applicable reliability and safety requirements. The framework’s primary measure is a societal cost test which, in addition to addressing avoided utility costs, is to quantitatively address certain environmental externalities and, where appropriate, qualitatively address other externalities. The NYSPSC directed the utilities to develop and file benefit cost analysis handbooks to guide DER providers in structuring their projects and proposals.

In June 2016, CECONY and O&R each filed initial DSIPs and benefit-cost handbooks with the NYSPSC, pursuant to which the companies provided additional system and planning information for third-party developers to facilitate the integration of DER in the distributed system platform. In November 2016, CECONY and O&R, with the other state electric utilities, filed a joint supplemental DSIP with the NYSPSC, pursuant to which the companies expanded on the initial DSIPs to address the tools, processes and protocols to be developed jointly to operate the grid to manage DER and support a retail market. The Utilities plan to develop their distribution system platforms as proposed and in conformance with the guidance of the NYSPSC.

The NYSPSC is conducting additional proceedings to consider certain REV-related matters, including proceedings on the value of DER and net energy metering.

The Companies are not able to predict the outcome of the REV proceeding or related proceedings or their impact.

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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 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. 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’ forecasted rate base by the pre-tax weighted average cost of capital determined in the rate plan. In general, rate base is the sum of the utility’s net plant and working capital less deferred taxes. 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 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

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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 event. The scorecard, which could also be applied by the NYSPSC for other outages or actions, was developed to work with the penalty and emergency response plan provisions of the New York Public Service Law. 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 a 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 March 2016, the NYSPSC approved emergency response plans submitted by CECONY and O&R, subject to certain modifications. In December 2016, CECONY and O&R submitted updated plans.

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. Pending proceedings include the REV proceeding and related proceedings, discussed above, and proceedings relating to data access; retail access; utility staffing levels; energy efficiency and renewable energy programs; low income customers and consumer protections. The Utilities are typically active participants in such proceedings.

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. It 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 companies that supply customers on market terms. To address the possibility of a disruption due to the unavailability of gas, generating units located in New York City that are capable of using either gas or oil as fuel may be required to use oil as fuel for certain periods and new generating units located in New York City are required to have dual fuel capability. 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.

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Competition

Distributed generation, such as solar energy production facilities, fuel cells and micro-turbines, provide alternative sources of energy for the Utilities’ electric delivery customers, as does oil for the Utilities’ gas delivery customers. In addition, steam customers may have alternative sources of heating and cooling for their buildings. Micro-grids and community-based micro-grids enable distributed generation to serve multiple locations and multiple customers. Other distributed energy resources, such as demand reduction and energy efficiency programs, provide alternatives for the Utilities’ delivery customers to manage their energy usage. The following table shows the aggregate capacities of the distributed generation projects connected to the Utilities’ distribution systems at the end of the last three years:

Technology	CECONY			O&R
Total MW, except project number	2014	2015	2016	2014	2015	2016
Internal-combustion engines	101	103	104	21	21	22
Photovoltaic solar	58	95	135	28	46	63
Gas turbines	40	40	40	—	—	—
Micro turbines	9	10	10	1	1	1
Fuel cells	8	8	9	—	—	—
Steam turbines	3	3	4	—	—	—
Landfill	—	—	—	2	2	2
Total distribution-level distributed generation	219	259	302	52	70	88
Number of distributed generation projects	4,200	7,451	12,928	1,881	3,704	5,376

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

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 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 N 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 $17,234 million and $16,394 million at December 31, 2016 and 2015, respectively. For its transmission facilities, the costs for utility plant, net of accumulated depreciation, were $2,963 million and $2,833 million at December 31, 2016 and 2015, respectively, and for its portion of the steam-electric generation facilities, the costs for utility plant, net of accumulated depreciation, were $479 million and $459 million, at December 31, 2016 and 2015, 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, 2016, the company’s distribution system had a transformer capacity of 30,122 MVA, with 36,900 miles of overhead distribution lines and 97,288 miles of underground distribution lines. The underground distribution lines represent the single longest underground electric delivery system in the United States.

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Transmission Facilities

The company’s transmission facilities are located in New York City and Westchester, Orange, Rockland, Putnam and Dutchess counties in New York State. At December 31, 2016, CECONY owned or jointly owned 438 miles of overhead circuits operating at 138, 230, 345 and 500 kV and 749 miles of underground circuits operating at 69, 138 and 345 kV. The company’s 39 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 726 MW. The company expects to have sufficient amounts of gas and fuel oil available in 2017 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 and economic development customers of municipal electric agencies.

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,
	2012	2013	2014	2015	2016
Electric Energy Delivered (millions of kWh)
CECONY full service customers	20,622	20,118	19,757	20,206	19,886
Delivery service for retail choice customers	25,990	26,574	26,221	26,662	26,813
Delivery service to NYPA customers and others	10,267	10,226	10,325	10,147	10,046
Delivery service for municipal agencies	322	—	—	—	—
Total Deliveries in Franchise Area	57,201	56,918	56,303	57,015	56,745
Electric Energy Delivered ($ in millions)
CECONY full service customers	$4,731	$4,799	$5,023	$4,757	$4,404
Delivery service for retail choice customers	2,750	2,683	2,646	2,714	2,768
Delivery service to NYPA customers and others	596	602	625	600	610
Delivery service for municipal agencies	10	—	—	—	—
Other operating revenues	89	47	143	101	324
Total Deliveries in Franchise Area	$8,176	$8,131	$8,437	$8,172	$8,106
Average Revenue per kWh Sold (Cents) (a)
Residential	25.6	27.0	28.9	26.3	24.9
Commercial and Industrial	20.0	20.6	22.1	20.6	19.1

(a) Includes Municipal Agency sales.

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 N 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 of2016was cooler than design conditions.CECONY’s 2016 service area peak demand was 12,652 MW, which occurred on August 11, 2016. The 2016 peak demand included an estimated 6,114 MW for

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CECONY’s full-service customers, 4,541 MW for customers participating in its electric retail choice program and 1,997 MW for NYPA’s electric commodity customers and municipal electric agency customers. “Design weather” for the electric system is a standard to which the actual peak demand is adjusted for evaluation and planning purposes. Since NYISO-invoked demand reduction programs can be called upon under specific circumstances, design conditions do not include these programs’ potential impact. However, the CECONY forecasted peak demand at design conditions does include the impact of certain demand reduction programs. The company estimates that, under design weather conditions, the 2017 service area peak demand will be 13,470 MW, including an estimated 6,559 MW for its full-service customers, 4,755 MW for its electric retail choice customers and 2,156 MW for NYPA’s customers and municipal electric agency customers. The company forecasts an average annual growth in electric peak demand in its service area at design conditions over the next five years to be approximately 0.2 percent per year.

Electric Supply

Most of the electricity sold by CECONY to its full-service customers in 2016 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 2017. 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 approximately 1,423 MW of electric generating capacity, see Notes I and O 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, 2016, the generating stations had a combined electric capacity of approximately 726 MW, based on 2016 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 purchased power costs, 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.

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. In addition, the NYISO has adopted reliability rules that include 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 November 2012, the NYSPSC directed CECONY to work with NYPA to develop a contingency plan to address reliability concerns associated with the potential closure of the nuclear power plant at the Indian Point Energy Center (which is owned by Entergy Corporation subsidiaries). In October 2013, the NYSPSC approved three transmission projects and several energy efficiency, demand reduction and combined heat and power programs to address concerns associated with the potential closure. The transmission projects were placed into service in May 2016. See “Con Edison Transmission” below. In February 2014, CECONY submitted to the NYSPSC the implementation plan for the energy efficiency, demand reduction and combined heat and power programs. In January 2017, New York State officials announced that, under an agreement reached with Entergy, one of the two nuclear reactors at Indian Point is scheduled to shut down by April 2020, while the other is scheduled to be closed a year later.

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Gas Operations

Gas Facilities

CECONY’s capitalized costs for utility plant, net of accumulated depreciation, for gas facilities, which are primarily distribution facilities, were $5,749 million and $5,196 million at December 31, 2016 and 2015, 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 4,375 miles of mains and 370,924 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 1,226MDt of additional natural gas storage capacity at a field in upstate New York, owned and operated by Honeoye Storage Corporation, a corporation 28.8 percent owned by CECONY and 71.2 percent owned by Con Edison Development.

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,
	2012	2013	2014	2015	2016
Gas Delivered (MDt)
Firm Sales
Full service	57,595	67,007	75,630	77,197	75,892
Firm transportation of customer-owned gas	52,860	61,139	68,731	72,864	68,442
Total Firm Sales	110,455	128,146	144,361	150,061	144,334
Interruptible Sales (a)	5,961	10,900	10,498	6,332	8,957
Total Gas Delivered to CECONY Customers	116,416	139,046	154,859	156,393	153,291
Transportation of customer-owned gas
NYPA	48,107	48,682	47,548	44,038	43,101
Other (mainly generating plants and interruptible transportation)	108,086	87,379	105,012	104,857	109,000
Off-System Sales	730	4,638	15	389	—
Total Sales	273,339	279,745	307,434	305,677	305,392
Gas Delivered ($ in millions)
Firm Sales
Full service	$889	$1,059	$1,141	$956	$933
Firm transportation of customer-owned gas	380	414	453	458	426
Total Firm Sales	1,269	1,473	1,594	1,414	1,359
Interruptible Sales	39	69	91	46	34
Total Gas Delivered to CECONY Customers	1,308	1,542	1,685	1,460	1,393
Transportation of customer-owned gas
NYPA	2	2	2	2	2
Other (mainly generating plants and interruptible transportation)	68	71	70	54	57
Off-System Sales	5	18	—	1	—
Other operating revenues (mainly regulatory amortizations)	32	(17)	(36)	11	56
Total Sales	$1,415	$1,616	$1,721	$1,528	$1,508
Average Revenue per Dt Sold
Residential	$18.14	$18.52	$16.76	$13.91	$13.96
General	$11.68	$12.05	$12.38	$9.73	$9.47

(a) Includes 563, 5,362, 6,057, 1,229 and 4,708 MDt for 2012, 2013, 2014, 2015 and 2016, respectively, which are also reflected in firm transportation and other.

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 N to the financial statements in Item 8.

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Gas Peak Demand

The gas peak demand for firm sales customers in CECONY’s service area occurs during the winter heating season. The peak day demand during the winter2016/2017(through January 31,2017) occurred on January 9, 2017 when the demand reached 1,155 MDt. The2016/2017peak day demand included 606 MDt for CECONY’s full-service customers and 549 MDt for customers participating in its gas retail choice program. “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, the2017/2018service area peak day demand will be 1,509 MDt, including an estimated 792 MDt for its full-service customers and 717 MDt for its gas retail choice customers.The forecasted peak day demand at design conditions does not include gas used by interruptible gas customers including electric and steam generating stations. The company forecasts an average annual growth of the gas peak demand over the next five years at design conditions to be approximately 2.3 percent in its service area.

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 S 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 amountedto approximately $301 million in 2016, including $263 million for CECONY. See “Contractual Obligations” below. At December 31, 2016, the contracts were for various terms extending to 2020 for supply and 2038 for transportation and storage. During 2016, CECONY entered into four 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 and Note P 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 $1,882 million and $1,849 million at December 31, 2016 and 2015, respectively. See "CECONY – Electric Operations – Electric Facilities," above.

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

Steam Sales and Deliveries

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

	Year Ended December 31,
	2012	2013	2014	2015	2016
Steam Sold (MMlb)
General	425	547	594	538	465
Apartment house	5,240	6,181	6,574	6,272	5,792
Annual power	14,076	15,195	15,848	15,109	13,722
Total Steam Delivered to CECONY Customers	19,741	21,923	23,016	21,919	19,979
Steam Sold ($ in millions)
General	$25	$31	$30	$29	$23
Apartment house	158	187	180	176	148
Annual power	429	491	469	453	378
Other operating revenues	(16)	(26)	(51)	(29)	2
Total Steam Delivered to CECONY Customers	$596	$683	$628	$629	$551
Average Revenue per MMlb Sold	$31.00	$32.34	$29.50	$30.02	$27.48

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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 N to the financial statements in Item 8.

Steam Peak Demand and Capacity

Demand for steam in CECONY’s service area peaks during the winter heating season. The one-hour peak demand during the winter of2016/2017(through January 31, 2017) occurred on January 9, 2017 when the demand reached 7.8 MMlb per hour. “Design weather” for the steam system is a standard to which the actual peak demand is adjusted for evaluation and planning purposes. The company’s estimate for the winter of2017/2018peak demand of its steam customers is about 8.9 MMlb per hour under design conditions. The company forecasts an average annual decrease in steam peak demand in its service area at design conditions over the next five years to be approximately0.7percent.

OnDecember 31, 2016, the steam system was capable of delivering approximately 11.6 MMlb of steam per hour, and CECONY estimates that the system will have the same capability in the 2017/2018 winter.

Steam Supply

38 percent of the steam produced by CECONY in 2016 was supplied by the company’s steam-only generating assets; 44 percent was produced by the company’s steam-electric generating assets, where steam and electricity are primarily cogenerated; and 18 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 $916 million and $850 million at December 31, 2016 and 2015, respectively. For its transmission facilities, the costs for utility plant, net of accumulated depreciation, were $221 million and $212 million at December 31, 2016 and 2015, respectively.

O&R and RECO own, in whole or in part, transmission and distribution facilities which include 532 circuit miles of transmission lines, 15 transmission substations, 62 distribution substations, 85,514 in-service line transformers, 3,913 pole miles of overhead distribution lines and 1,764 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 margin or profit on the electricity it sells. O&R’s New York electric revenues (which accounted for 74 percent of O&R’s electric revenues in 2016) 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:

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	Year Ended December 31,
	2012	2013	2014	2015	2016
Electric Energy Delivered (millions of kWh)
Total deliveries to O&R full service customers	2,691	2,555	2,429	2,499	2,555
Delivery service for retail choice customers	3,040	3,166	3,240	3,237	3,180
Total Deliveries In Franchise Area	5,731	5,721	5,669	5,736	5,735
Electric Energy Delivered ($ in millions)
Total deliveries to O&R full service customers	$405	$427	$455	$441	$426
Delivery service for retail choice customers	178	192	207	213	213
Other operating revenues	9	9	18	9	(2)
Total Deliveries In Franchise Area	$592	$628	$680	$663	$637
Average Revenue Per kWh Sold (Cents)
Residential	16.7	18.1	20.3	19.2	18.4
Commercial and Industrial	13.0	14.8	16.8	15.4	14.3

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 N to the financial statements in Item 8.

Electric Peak Demand

The electric peak demand in O&R’s service area occurs during the summerair conditioning season. The weather during the summer of 2016 was cooler than design conditions. O&R’s 2016 service area peak demand was1,435 MW, which occurred on July 22, 2016. The2016peak demand included an estimated 761 MW for O&R’sfull-service customers and 674 MW for customers participating in its electric retail choice program. “Design weather” for the electric system is a standard to which the actual peak demand is adjusted for evaluation and planning purposes. Since the NYISO can invoke demand reduction programs under specific circumstances, design conditions do not include these programs’ potential impact. However, the O&R forecasted peak demand at design conditions does include the impact of certain demand reduction programs. The company estimates that, under design weather conditions, the2017service area peak demand will be 1,625 MW, including an estimated 861 MW for its full-service customers and 764 MW for its electric retail choice customers. The company decreased its five-year forecast of average annual growth of the electric peak demand in its service area at design conditions from approximately 0.3 percent (for 2016 to 2020) to (0.1) percent (2017 to 2021) primarily due to a forecasted increase in distributed generation as well as lower growth in demand from customers. Pike's peak demand is reflected in thecompany's service area peak demand amounts (see Note U to the financial statements in Item 8).

Electric Supply

The electricity O&R sold to its full-service customers in 2016 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 2017. 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 O to the financial statements in Item 8.

In general, the Utilities recover their purchased power costs, 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 $536 million and $502 million at December 31, 2016 and 2015, respectively. Natural gas 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 1,865 miles of mains and 104,748 service lines.

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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. O&R’s New York gas revenues (which have accounted for substantially all of O&R’s gas revenues) are subject 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,
	2012	2013	2014	2015	2016
Gas Delivered (MDt)
Firm Sales
Full service	7,539	8,808	9,529	9,348	9,723
Firm transportation	10,505	12,062	12,592	11,752	10,381
Total Firm Sales	18,044	20,870	22,121	21,100	20,104
Interruptible Sales	4,326	4,118	4,216	4,205	3,853
Total Gas Delivered to O&R Customers	22,370	24,988	26,337	25,305	23,957
Transportation of customer-owned gas
Sales for resale	793	885	945	906	867
Sales to electric generating stations	15	19	70	25	18
Off-System Sales	—	—	3	62	16
Total Sales	23,178	25,892	27,355	26,298	24,858

	Year Ended December 31,
	2012	2013	2014	2015	2016
Gas Delivered ($ in millions)
Firm Sales
Full service	$103	$115	$121	$91	$99
Firm transportation	76	77	75	68	70
Total Firm Sales	179	192	196	159	169
Interruptible Sales	4	3	2	3	3
Total Gas Delivered to O&R Customers	183	195	198	162	172
Transportation of customer-owned gas
Sales to electric generating stations	—	—	1	—	—
Other operating revenues	20	10	13	20	12
Total Sales	$203	$205	$212	$182	$184
Average Revenue Per Dt Sold
Residential	$14.01	$13.31	$13.01	$10.11	$10.71
General	$11.99	$11.53	$11.30	$8.24	$8.17

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 N to the financial statements in Item 8.

Gas Peak Demand

The gas peak demand for firm sales customers in O&R’s service area occurs during the winter heating season. The peak day demand during the winter 2016/2017 (through January 31, 2017) occurred on January 8, 2017 when the demand reached 173 MDt. The 2016/2017 peak day demand included 83 MDt for O&R’s full-service customers and 90 MDt for customers participating in its gas retail choice program. “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 2017/2018 service area peak day demand will be 222 MDt, including an estimated 107 MDt for its full-service customers and 115 MDt for its gas retail choice customers. 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 demand over the next five years at design conditions to be approximately 0.2 percent in its service area. Pike’s peak demand is reflected in the company’s service area peak demand amounts (see Note U to the financial statements in Item 8).

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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.

Clean Energy Businesses

Con Edison Development

Con Edison Development develops, owns and operates renewable and energy infrastructure projects. The company focuses its efforts on renewable electric production projects, and at the end of 2015 was the fifth largest owner of operating photovoltaic solar capacity in the United States. 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 Con Edison Development's renewable electric production projects in operation at the end of the last five years:

Generating Capacity (MW AC)	2012	2013	2014	2015	2016
Renewable electric production projects	127	292	446	748	1,098

The following table provides information about the projects the company owned at December 31, 2016:

Project Name	Production Technology	Generating Capacity (a) (MW AC)	PPA Term (In Years) (b)	Actual/Expected In-Service Date (c)	Location (State)
Wholly owned projects
Pilesgrove	Solar	18	n/a (d)	2011	New Jersey
Flemington Solar	Solar	8	n/a (d)	2011	New Jersey
Frenchtown I, II and III	Solar	14	n/a (d)	2011-13	New Jersey
PA Solar	Solar	10	n/a (d)	2012	Pennsylvania
California Solar 2 (e)	Solar	80	20	2014-16	California
Oak Tree Wind	Wind	20	20	2014	South Dakota
Texas Solar 3	Solar	6	25	2015	Texas
Texas Solar 5 (e)	Solar	95	25	2015	Texas
Campbell County Wind	Wind	95	30	2015	South Dakota
Texas Solar 7 (e)	Solar	106	25	2016	Texas
California Solar 3 (Partial) (e)	Solar	75	20	2016	California
Adams Wind (e)	Wind	23	7	2016	Minnesota
Valley View (e)	Wind	10	14	2016	Minnesota
Coram (e)	Wind	102	16	2016	California
Projects of less than 5 MW	Solar / Wind	25	Various	Various	Various
Jointly owned projects (e) (f)
California Solar	Solar	55	25	2012-13	California
Mesquite Solar 1	Solar	83	20	2013	Arizona
Copper Mountain Solar 2	Solar	75	25	2013-15	Nevada
Copper Mountain Solar 3	Solar	128	20	2014-15	Nevada
Broken Bow II	Wind	38	25	2014	Nebraska
Texas Solar 4	Solar	32	25	2014	Texas
Total MW (AC) in Operation		1,098
California Solar 3 (Partial) (e)	Solar	35	20	2017	California
Upton County	Solar	158	25	2017	Texas
Panoche Valley	Solar	240	20	2019	California
Total MW (AC) in Construction		433
Total MW (AC), All Projects		1,531

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(a) Represents Con Edison Development’s ownership interest in the project.

(b) Represents PPA contractual term or remaining term from Con Edison Development’s date of acquisition.

(c) Represents Actual/Expected In-Service Date or Con Edison Development's date of acquisition.

(d) New Jersey, Pennsylvania and Massachusetts assets have 3-4 year Solar Renewable Energy Credit hedges in place.

(e) Project has been pledged to secure financing for the project.

(f) All of the jointly-owned projects are 50 percent owned, except for Texas Solar 4 (which is 80 percent owned). See Note Q to the financial statements in Item 8.

Con Edison Energy

Con Edison Energy provides services to manage the dispatch, fuel requirements and risk management activities for 4,014 MW of generating plants and merchant transmission in the northeastern United States owned by unrelated parties and manages energy supply assets leased from others. The company also provides wholesale hedging and risk management services to renewable electric production projects owned by Con Edison Development and Con Edison Solutions.

Con Edison Solutions

Con Edison Solutions provides 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. The company is compensated for its services based primarily on the increased energy efficiency of the installed equipment over a multi-year period. Con Edison Solutions has won competitive solicitations for energy savings contracts with the United States Department of Energy and the United States Department of Defense, and a shared energy savings contract with the United States Postal Service. The company also develops, owns and operates behind-the-meter renewable energy projects, predominately in Massachusetts and California, with an aggregate capacity of 44 MW (AC).

In September 2016, Con Edison Solutions sold its retail electric supply business, which primarily sold electricity to industrial, commercial and governmental customers in the northeastern United States and Texas and also sold electricity to residential and small commercial customers (mass market) in the northeastern United States. See Note U to the financial statements in Item 8. Con Edison Solutions’ electricity sales for the last five years were:

	2012	2013	2014	2015	2016
Retail electric volumes sold (millions of kWh)	13,840	12,167	11,871	13,594	9,843

For information about the Clean Energy Businesses' results, see "Results of Operations" in Item 7 and Note N 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 existing projects include three (called the TOTS Projects) that the NYSPSC approved 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 be able to operate. The TOTS Projects include the two projects that CECONY developed and transferred to the NY Transco (see Note U to the financial statements in Item 8) and one project that another regulated affiliate of NY Transco developed.

In April 2015, FERC issued an order granting certain transmission incentives for NY Transco projects. In March 2016, the FERC approved a November 2015 settlement agreement that provides for a 10 percent return on common equity (and/or 9.5 percent for capital costs in excess of $228 million incurred for initial commercial operation) and a maximum common equity ratio of 53 percent. The costs of the projects are allocated across New York State, with 63 percent 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 transmission projects that would relieve transmission congestion between upstate and downstate. The NYSPSC determined that there is a public policy need for new transmission to address the congestion, such as a project ($1,000 million estimated cost) proposed on behalf of NY Transco. This NY Transco project, which could be completed in the 2019 to 2021 timeframe, would be developed, at least initially, by National Grid and NY Transco. The NYSPSC also directed certain developers, including NY Transco, to submit project(s) to the NYISO. The NYISO evaluated the submitted projects under its FERC-approved public policy planning process and, in October 2016, submitted its list of viable

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and sufficient projects (including the NY Transco project) to the NYSPSC for its determination as to whether the transmission need still exists. In January 2017, the NYSPSC found that the public policy need still exists, asking the NYISO to proceed with selection. The NYISO may select one or more of the viable and sufficient projects for development. The cost of the project(s) selected by the NYISO would be recoverable through the NYISO’s tariff after FERC approves the rates for the project(s).

CET Gas

CET Gas, through its subsidiaries, owns a 50 percent interest in Stagecoach Gas Services LLC (Stagecoach) and a 12.5 percent ownership interest in Mountain Valley Pipeline LLC (MVP). Stagecoach is a joint venture with a subsidiary of Crestwood Equity Partners LP 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 S to the financial statements in Item 8) through its 181 miles of pipe and 41 Bcf of storage capacity. MVP is a joint venture with four other partners developing a proposed 300 mile gas transmission project in West Virginia and Virginia. MVP has indicated that the project has an estimated total cost of $3,000 million to $3,500 million, and subject to FERC approval, is targeted to be fully in-service during the fourth quarter of 2018. See Note U to the financial statements in Item 8.

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

Capital Requirements and Resources

Capital Requirements

The following table contains the Companies’ capital requirements for the years 2014 through 2016 and their current estimate of amounts for 2017 through 2019:

	Actual			Estimate
(Millions of Dollars)	2014	2015	2016	2017	2018	2019
CECONY (a)(b)
Electric	$1,500	$1,658	$1,819	$1,957	$1,919	$1,798
Gas	549	671	811	935	953	983
Steam	83	106	126	70	71	68
Sub-total	2,132	2,435	2,756	2,962	2,943	2,849
O&R
Electric	105	114	114	136	151	148
Gas	37	46	52	56	58	52
Sub-total	142	160	166	192	209	200
Con Edison Transmission
CET Electric	—	—	51	—	19	19
CET Gas	—	—	1,027	90	313	93
Sub-total	—	—	1,078	90	332	112
Clean Energy Businesses	447	823	1,235	450	400	400
Total capital expenditures	2,721	3,418	5,235	3,694	3,884	3,561
Retirement of long-term securities
Con Edison – parent company	2	2	2	2	402	3
CECONY	475	350	650	—	1,200	475
O&R	3	143	79	4	55	62
Clean Energy Businesses	5	4	4	33	31	34
Total retirement of long-term securities	485	499	735	39	1,688	574
Total capital requirements	$3,206	$3,917	$5,970	$3,733	$5,572	$4,135

(a) CECONY’s capital expenditures for environmental protection facilities and related studies were $218 million, $224 million and $259 million in 2014, 2015 and 2016, respectively, and are estimated to be $372 million in 2017.

(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.

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Estimated capital expenditures for Con Edison Transmission primarily reflect planned investments in the MVP gas transmission project. 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, 2016 to make payments pursuant to contracts. Long-term debt, capital lease obligations and other noncurrent liabilities are included on their 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.

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	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	$12,186		$—	$1,675	$350	$10,161
O&R	671	4		117	—	550
Clean Energy Businesses	845	33		65	72	675
Parent	1,206	2		405	506	293
Interest on long-term debt (a)	12,709	719		1,251	1,115	9,624
Total long-term debt, including interest	27,617	758		3,513	2,043	21,303
Capital lease obligations (Note J)
CECONY	2	1		1	—	—
Total capital lease obligations	2	1		1	—	—
Operating leases (Notes J and Q)
CECONY	964	53		108	107	696
O&R	5	1		2	1	1
Clean Energy Businesses	122	7		13	11	91
Total operating leases	1,091	61		123	119	788
Purchase obligations
Electricity purchase power agreements – Utilities (Note I)
CECONY
Energy	2,661	390		202	202	1,867
Capacity (b)	1,506	255		412	129	710
Total CECONY	4,167	645		614	331	2,577
O&R
Energy and Capacity (b)	91	57		33	1	—
Total electricity and purchase power agreements – Utilities	4,258	702		647	332	2,577
Natural gas supply, transportation, and storage contracts – Utilities (c)
CECONY
Natural gas supply	296	212		80	4	—
Transportation and storage	2,680	241		463	375	1,601
Total CECONY	2,976	453		543	379	1,601
O&R
Natural gas supply	29	18		11	—	—
Transportation and storage	499	45		86	70	298
Total O&R	528	63		97	70	298
Total natural gas supply, transportation and storage contracts	3,504	516		640	449	1,899
Other purchase obligations
CECONY (d)	4,845	1,529		1,814	677	825
O&R (d)	195	85		86	23	1
Clean Energy Businesses (e)	581	482		91	3	5
Total other purchase obligations	5,621	2,096		1,991	703	831
Uncertain tax positions (f)	12	12		—	—	—
Total	$42,105	$4,146		$6,915	$3,646	$27,398

(a) Includes interest on variable rate debt calculated at rates in effect at December 31, 2016.

(b) Included in these amounts is the cost of minimum quantities of energy that the company is 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. 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 to purchase minimum quantities of electric energy and capacity, renewable energy certificates, natural gas, natural gas pipeline capacity, energy efficiency services and construction services entered into by the Clean Energy Businesses.

(f) Con Edison reasonably expects to resolve approximately $35 million of its liability for uncertain tax positions within the next twelve months, of which an estimated $12 million may be settled in cash payments. Con Edison is unable to reasonably estimate the timing of the

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resolution of its remaining liability for uncertain tax positions, which will depend on the progress of tax examinations with the various tax authorities. See Note L to the financial statements in Item 8. 

The Companies’ commitments to make payments in addition to these contractual commitments include their other liabilities reflected in 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 guarantees of certain obligations of the Clean Energy Businesses and CET - Electric. See Notes E, F, O 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 and the sale of its securities. Con Edison’s ability to make payments on external borrowings and dividends on its common shares depends on receipt of dividends from its subsidiaries or proceeds from the sale of its securities or its interests in its subsidiaries.

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 and revolving credit agreements with banks, 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. 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. For information about the Companies’ long-term debt and short-term borrowing, see Notes C and D to the financial statements in Item 8.

Con Edison plans to meet its 2017 capital requirements through internally-generated funds and the issuance of securities. The company’s plans include the issuance of between $1,000 million and $1,800 million of long-term debt, most of which would be at the Utilities, and the issuance of additional debt secured by its renewable electric production projects. The company’s plans also include the issuance of up to $350 million of common equity in addition to equity under its dividend reinvestment, employee stock purchase and long term incentive plans.

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.

In 2016, the NYSPSC authorized CECONY, through 2019, to issue up to $5,200 million of debt securities ($1,300 million of which the company had issued as of December 31, 2016). In 2013, the NYSPSC authorized O&R, through 2017, to issue up to $305 million of debt securities ($295 of which the company had issued as of December 31, 2016). The NYSPSC also authorized CECONY and O&R for such periods to issue up to $2,500 million and $125 million, respectively, of debt securities to refund existing debt securities. At December 31, 2016, the Utilities had not refunded any securities pursuant to this authorization.

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 "Liquidity and Capital Resources" in Item 7.

For each of the Companies, the ratio of earnings to fixed charges (SEC basis) for the last five years was:

	Ratio of Earnings to Fixed Charges
	2012	2013		2014	2015	2016
Con Edison	3.7	3.0	(a)	3.6	3.5	3.6
CECONY	3.7	3.7		3.8	3.6	3.6

(a) Reflects $95 million after-tax charge to earnings relating to Con Edison Development’s LILO transactions that were terminated in 2013.

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

	Common Equity Ratio (Percent of total capitalization)
	2012	2013	2014	2015	2016
Con Edison	54.3	54.0	52.2	52.1	49.3
CECONY	53.7	53.8	50.9	51.4	49.5

The commercial paper of Con Edison and O&R is rated P-2, A-2 and F2, respectively, by Moody’s, S&P and Fitch. The commercial paper of CECONY is rated P-1, A-2 and F2 by Moody’s, S&P and Fitch, respectively. The senior unsecured debt of Con Edison is rated A3, BBB+ and BBB+ by Moody's, S&P and Fitch, respectively. The senior unsecured debt of CECONY is rated A2, A- and A- by Moody’s, S&P and Fitch, respectively. The senior unsecured debt of O&R is rated A3, A- and A- by Moody’s, S&P and Fitch, respectively. Securities ratings assigned by rating organizations are expressions of opinion and are not recommendations to buy, sell or hold securities. A securities 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.

CECONY has $636 million of tax-exempt debt for which the interest rates are to be determined pursuant to periodic auctions. Of this amount, $391 million is insured by Ambac Assurance Corporation and $245 million is insured by Syncora Guarantee Inc. (formerly XL Capital Assurance Inc.). Credit rating agencies have withdrawn the ratings of these insurers. Subsequently, there have not been sufficient bids to determine the interest rates pursuant to auctions, and interest rates have been determined by reference to a variable rate index. The weighted average annual interest rate on this tax-exempt debt was 1.00 percent onDecember 31, 2016. The weighted average interest rate was 0.75 percent, 0.14 percent and 0.10 percent for the years 2016, 2015 and 2014, respectively. Under CECONY’s current electric, gas and steam rate plans, variations in auction rate debt interest expense are reconciled to the levels set in rates.

Environmental Matters

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-related events. In late October 2012, Superstorm Sandy caused extensive damage to the Utilities’ electric distribution system. Superstorm Sandy interrupted service to approximately 1.4 million of the Utilities’ customers – more than four times the number of customers impacted by the Utilities’ previous worst storm event (Hurricane Irene in 2011) and resulted in the Utilities incurring substantial response and restoration costs.

Based on the most recent data (2015) 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. Con Edison’s estimated emissions of GHG during the past five years were:

(Metric tons, in millions (a))	2012	2013	2014	2015	2016
CO2 equivalent emissions	3.3	3.4	3.2	3.2	3.1

(a) Estimated emissions for 2016 are based on preliminary data and are subject to third-party verification.

Con Edison’s 49 percent decrease in direct GHG emissions (carbon dioxide, methane and sulfur hexafluoride) since 2005 (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, by operating system components at lower pressure, and by introducing new technologies to prioritize leak repairs and to reduce losses 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 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.

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NYSERDA and New York utilities have been responsible for implementing the Energy Efficiency Portfolio Standard (EEPS) established by the NYSPSC through energy efficiency programs designed and managed by NYSERDA and the utilities and authorized by the NYSPSC. CECONY billed customers EEPS surcharges of approximately $103 million in 2015 and 2014 to fund these programs. EEPS authorization ended December 2015. Beginning January 2016, New York utilities have implemented Energy Efficiency Transition Implementation Plans (ETIPs) and are responsible for designing and managing their energy efficiency programs consistent with NYSPSC-approved, utility-specific program budgets and metrics. Effective January 2016, the utilities are recovering the costs of their ETIP programs from their customers primarily through NYSPSC-approved energy efficiency tracker surcharge mechanisms. The Utilities billed customers $107 million in 2016 through the tracker surcharge mechanism. Pursuant to CECONY's current electric rate plan, the company will supplement its existing ETIP programs with new energy efficiency, electric vehicle and system peak reduction programs, the cost of which will be reflected in base rates. See Note B to the financial statements in Item 8. The estimated costs of the existing and new programs are approximately $120 million, $150 million, and $210 million in 2017, 2018, and 2019, respectively.

Through the Utilities' energy-efficiency programs, customers reduced their annual energy use by approximately 1,249,000 MWh of electricity and 1,702,000 Dth of gas from the programs’ inception in 2009 through 2016, resulting in their avoiding their release of approximately 765,000 tons of GHG into the atmosphere in 2016. In addition, CECONY’s other demand-side management programs assisted customers in reducing their annual energy use by approximately 336,000 MWh of electricity from the programs’ inception in 2004 through 2016, resulting in their avoiding their release of approximately 189,000 tons of GHG into the atmosphere in 2016.

Emissions are also avoided by renewable electric production facilities replacing fossil-fueled electric production facilities. NYSERDA has been responsible for implementing the renewable portfolio standard (RPS) established by the NYSPSC. NYSERDA has entered into long-term agreements with developers of large renewable electric production facilities and pays them premiums based on the facilities’ electric output. These facilities sell their energy output in the wholesale energy market 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. The Utilities billed customers RPS surcharges of $19 million and $131 million in 2016 and 2015, respectively, (and approximately $697 million cumulatively from 2006) to fund these NYSERDA programs. In March 2016, NYSERDA reported that the statewide environmental benefits of having electricity generated by renewable production facilities from 2006 through 2015, as opposed to the State’s “system-mix,” amounts to approximately 6,700 tons of nitrogen oxides, 12,200 tons of sulfur dioxides and 6.4 million tons of carbon dioxide in reduced emissions over this time period. In January 2016, the NYSPSC approved a 10-year $5.3 billion 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 have eliminated the separate RPS tariff and now 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 $277 million in 2016. For information about NYSPSC proceedings considering renewable generation see “Utility Regulation – State Utility Regulation – New York Utility Industry – Reforming the Energy Vision," above.

In June 2015, the New York State Energy Planning Board released its 2015 State Energy Plan. Under New York State law, any energy-related action or decision of State agencies must be reasonably consistent with the plan. The plan reflects clean energy initiatives, including the REV proceeding, NYSERDA’s clean energy fund and the following goals for New York State to meet by 2030: a 40 percent reduction in greenhouse gas emissions from 1990 levels; 50 percent of electric generation from renewable energy sources; and a 23 percent decrease in energy consumption in buildings from 2012 levels. For information about the NYSPSC's adoption of a clean energy standard to mandate achievement of the State Energy Plan's goals, see "Utility Regulation – State Utility Regulation – New York Utility Industry – Reforming the Energy Vision," above. Also, New York State and New York City have announced goals to reduce GHG emissions 80 percent below 1990 and 2005, respectively, levels by 2050.

In August 2015, the United States Environmental Protection Agency (EPA) issued its Clean Power Plan to reduce carbon dioxide emissions from existing power plants 32 percent from 2005 levels by 2030. Under the Clean Power Plan, each state is 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 is approximately 20 percent below its 2012 emissions rate. State plans may, among other things, include participation in regional cap-and-trade programs,

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such as the Regional Greenhouse Gas Initiative (RGGI), and renewable energy and energy efficiency programs. In February 2016, the Supreme Court of the United States stayed the implementation of the Clean Power Plan until the resolution of litigation challenging the plan.

CECONY is subject to carbon dioxide emissions regulations established by New York State under 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. CECONY met its requirement of 6.3 million allowances for the most recent RGGI compliance period (2012-2014) and has purchased sufficient allowances to meet its requirement for the current compliance period (2015-2017).

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

Environmental Sustainability

Con Edison’s sustainability strategy, as it relates to the environment, provides that the company seeks to reduce its environmental footprint by making effective use of natural resources to address the challenges of climate change and its impact on the company’s business. 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.

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 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, 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 New York State Department of Environmental Conservation (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 six 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 three sites under the NYS Brownfield Cleanup Program and Certificates of Completion have been issued by the NYSDEC for these sites. Remedial design is ongoing for the remaining 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 $469 million to $2,260 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

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environmental contamination is found and action is necessary, to remediate the contamination. The company’s investigations are ongoing. The company has submitted to the NYSDEC and the New York State Department of Health reports 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 rangefrom $162 million to $475 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 $506.1 million (and indicated the actual cost could be significantly higher or lower). 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 has 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 $62 million. CECONY is participating with other PRPs in an allocation process to determine each PRP’s share of the liability for these remedial design costs. In June 2015, other Federal agencies and the NYSDEC 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.

Other Superfund Sites

In September 2007, the NYSDEC demanded that the company investigate and remediate PCB contamination that may have migrated from a former CECONY service center facility in Flushing New York, into the adjacent Flushing River. In April 2008, the company and NYSDEC entered into a consent order under which the company agreed to implement a NYSDEC-approved investigation program for the Flushing River and, if deemed necessary by the NYSDEC to protect human health and the environment, to implement a NYSDEC-approved remediation program for any PCB contamination in the river attributable to the site. In March 2011, the company submitted to NYSDEC a report indicating that PCBs had migrated from the site to sediment in a portion of the river. In August 2013, the NYSDEC selected a remedy that requires the company to submit a remedial design report, remove contaminated sediment, restore the river bed with clean material, prepare a site management plan and implement institutional controls. The company estimates that its undiscounted potential liability for the completion of the cleanup in Flushing River could range from $5 million to $6 million.

In November 2016, the U.S. Coast Guard ordered CECONY and another utility to take certain response actions to locate, secure, contain and remove a discharge of dielectric fluid at a New Jersey marina located on the Hudson River from one or two underwater transmission lines, and ordered the marina owner to remove substantial debris from its collapsed pier that is blocking access to the lines. The other utility owns and operates the portion of the transmission lines located in New Jersey. CECONY owns and operates the portion of the transmission lines located in New York.  Consistent with prior arrangements between CECONY and the other utility for these lines, which included cost allocation provisions, CECONY has been responding to the incident on behalf of the other utility. In response to CECONY’s request for reconsideration to the U.S. Coast Guard, in which CECONY asserted that it is not a responsible party for the dielectric fluid discharge but would continue, on behalf of the other utility, to take actions necessary to respond to the dielectric fluid discharge, the U.S. Coast Guard rescinded its order to CECONY. CECONY does not expect that its share, if any, of the costs to respond to the discharge (which is ongoing) and repair the other utility’s portion of the transmission lines will have a material adverse effect on its financial condition, results of operation 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

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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 companycurrently 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.

Site	Location	Start	Court or Agency	% of Total Liability
Curcio Scrap Metal	Saddle Brook, NJ	1987	EPA	100%
Metal Bank of America	Philadelphia, PA	1987	EPA	1.0%
Cortese Landfill	Narrowsburg, NY	1987	EPA	6.0%
Global Landfill	Old Bridge, NJ	1988	EPA	0.3%
Borne Chemical	Elizabeth, NJ	1997	NJDEP	0.7%

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 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 three sites and remedial construction is in progress at one site. Remedial design is ongoing for the remaining two 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 $97 million to $151 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
Borne Chemical	Elizabeth, NJ	1997	NJDEP	2.3%
Metal Bank of America	Philadelphia, PA	1993	EPA	4.6%
Ellis Road	Jacksonville, FL	2011	EPA	0.2%

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Other Federal, State and Local Environmental Provisions

Toxic Substances Control Act

Virtually all electric utilities, including CECONY, 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.

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 generating 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 2016 and expects to comply with the rule in 2017. If changes to the Transport Rule that have been proposed are adopted, the number of allowances allocated to CECONY would decrease and the company would be required to purchase allowances to offset the decreased allocation.

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.

Employees

At December 31, 2016, Con Edison had no employees other than those of CECONY, O&R, and the Clean Energy Businesses (which had 13,531, 1,145 and 284 employees, respectively). In January 2017, 8 CECONY employees transferred to Con Edison Transmission. Of the CECONY and O&R employees, 8,196 and 593 employees, respectively, were represented by a collective bargaining unit. The collective bargaining agreement covering most of these CECONY employees expires in June 2020. Agreements covering other CECONY employees and O&R employees expire in June 2017 and May 2017, respectively.

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.

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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:

Regulatory/Compliance Risks:

The Companies Are Extensively Regulated And Are Subject To 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 penalties for failing to meet certain operating and customer satisfaction standards. See Note B to the financial statements in Item 8. FERC has the authority to impose penalties on the Utilities and the Clean Energy Businesses, 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. In April 2014, the NYSPSC instituted its REV proceeding to improve system efficiency and reliability, encourage renewable energy resources, support distributed energy resources and empower customer choice. See “Utility Regulation” and “Environmental Matters – Climate Change and Other Federal, State and Local Environmental Provisions” in Item 1 and “Application of Critical Accounting Policies” in Item 7.

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. State utility regulators can initiate proceedings to prohibit the Utilities from recovering from their customers the cost of service (including energy 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.

The Intentional Misconduct of Employees or Contractors Could Adversely Affect the Companies.    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. Such intentional misconduct by employees or contractors could result in substantial liability, higher costs and increased regulatory requirements. See “Employees” in Item 1.

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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. A natural disaster such as a major storm, a heat wave or hurricane 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 Steam Main Rupture" 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" in Item 1.

A Cyber Attack Could Adversely Affect the Companies.    The Utilities and other operators of critical energy infrastructure face a heightened risk of cyber attack. The U.S. Department of Energy's Quadrennial Energy Review, issued in January 2017, indicated that cyber threats to the electricity system are increasing in sophistication, magnitude, and frequency. In the event of a cyber attack that the Companies were unable to defend against or mitigate, the Companies could have their operations disrupted, financial and other information systems 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 and damage to their reputation. The Companies have experienced cyber attacks, although none of the attacks had a material impact.

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. See “Environmental Matters – Climate Change” 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 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 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. In addition, see “Financial and Commodity Market Risks” in Item 7.

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 to the financial statements in Item 8.

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The Companies Require Access To Capital Markets To Satisfy Funding Requirements.    The Utilities estimate that their construction expenditures will exceed $9 billion 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 and Con Edison Transmission are investing in renewable generation and 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 and the sale of its securities. 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. Changes to tax laws that would have the effect of reducing Con Edison’s taxable income could adversely affect the company’s ability to use its renewable energy tax credits. See Note L to the financial statements in Item 8.

Other Risks:

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 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 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. See “Utility Regulation – State Utility Regulation – New York Utility Industry – Reforming the Energy Vision,” and “Competition” 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 directly influences 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 Company 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, the Clean Energy Businesses and Con Edison Transmission.

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).

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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, “Superfund Sites” and “Asbestos Proceedings” in Note G and “Manhattan Steam Main Rupture” 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.

Executive Officers of the Registrant

The following table sets forth certain information about the executive officers of Con Edison and CECONY as of February 16, 2017. As indicated, certain of the executive officers are executive officers of each of Con Edison and CECONY and others are executive officers of Con Edison or CECONY. 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
Executive Officers of Con Edison and CECONY
John McAvoy	56	5/14 to present – Chairman of the Board, President and Chief Executive Officer and Director of Con Edison and Chairman, Chief Executive Officer and Trustee of CECONY
		12/13 to 4/14 – President and Chief Executive Officer and Director of Con Edison and Chief Executive Officer and Trustee of CECONY
		1/13 to 11/13 – President and Chief Executive Officer of O&R
		12/12 – Senior Vice President of CECONY
		2/09 to 11/12 – Senior Vice President – Central Operations of CECONY
Craig S. Ivey	54	12/09 to present – President of CECONY
Robert Hoglund	55	9/05 to present – Senior Vice President and Chief Financial Officer of Con Edison and CECONY
Elizabeth D. Moore	62	5/13 to present – Senior Vice President and General Counsel of Con Edison and CECONY
		5/09 to 4/13 – General Counsel of Con Edison and CECONY
Frances A. Resheske	56	2/02 to present – Senior Vice President – Corporate Affairs (formerly known as Public Affairs) of CECONY
Robert Sanchez	51	9/16 to present – Senior Vice President - Corporate and Shared Services of CECONY
		9/14 to 8/16 Vice President - Brooklyn & Queens Electric Operations of CECONY
		5/11 to 8/14 Vice President - System & Transmission Operations of CECONY
Saumil P. Shukla	57	9/15 to present – Senior Vice President – Utility Shared Services of CECONY
		10/14 to 8/15 – Vice President – Supply Chain (Shared Services)
		9/07 to 9/14 – Vice President - Steam Operations of CECONY
Robert Muccilo	60	7/09 to present – Vice President and Controller of Con Edison and CECONY
		11/09 to present – Chief Financial Officer and Controller of O&R
Gurudatta Nadkarni	51	1/08 to present – Vice President of Strategic Planning of CECONY
Yukari Saegusa	49	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
		12/08 to 3/13 – Managing Director, Debt Capital Markets at Barclays Capital
Executive Officers of Con Edison but not CECONY
Timothy P. Cawley	52	12/13 to present – President and Chief Executive Officer of O&R
		11/13 – Senior Vice President of CECONY
		12/12 to 10/13 – Senior Vice President – Central Operations of CECONY
		5/11 to 11/12 – Vice President – Substation Operations of CECONY
Mark Noyes	52	12/16 to present – President and Chief Executive Officer of Con Edison Clean Energy Businesses, Inc.

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		5/16 to present – President and Chief Executive Officer of Con Edison Solutions
		10/15 to present – President and Chief Executive Officer of Con Edison Development and Con Edison Energy
		10/14 to 9/15 – Senior Vice President and Chief Operating Officer of Con Edison Development and Con Edison Energy
		3/09 to 9/14 – Vice President of Con Edison Development
Joseph P. Oates	55	9/16 to present – President and Chief Executive Officer of Con Edison Transmission, Inc.
		1/16 to 8/16 – President of Con Edison Transmission, Inc.
		9/15 to 8/16 – Senior Vice President - Corporate Shared Services of CECONY
		9/12 to 8/15 – Senior Vice President – Business Shared Services of CECONY
		7/12 to 8/12 – Senior Vice President of CECONY
		7/07 to 6/12 – Vice President – Energy Management of CECONY
Executive Officers of CECONY but not Con Edison
(All offices and positions listed are with CECONY)
Milovan Blair	54	11/13 to present – Senior Vice President – Central Operations
		10/13 – Vice President
		5/11 to 9/13 – Vice President – Brooklyn and Queens Electric Operations
Marilyn Caselli	62	5/05 to present – Senior Vice President – Customer Operations
Marc E. Huestis	56	2/15 to present – Senior Vice President – Gas Operations
		1/15 – Senior Vice President
		2/14 to 12/14 – Vice President – Manhattan Electric Operations
		1/14 – Vice President
		10/08 to 12/13 – Vice President – Construction
Robert D. Schimmenti	52	9/14 to present – Senior Vice President – Electric Operations
		5/10 to 8/14 – Vice President – Engineering and Planning

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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. As of January 31, 2017, there were 46,650 holders of record of Con Edison’s Common Shares.

The market price range for Con Edison’s Common Shares during 2015 and 2016, as reported in the consolidated reporting system, and the dividends paid by Con Edison in 2015 and 2016 were as follows:

	2015			2016
	High	Low	Dividends Paid	High	Low	Dividends Paid
1st Quarter	$72.25	$58.65	$0.65	$77.02	$63.47	$0.67
2nd Quarter	$63.03	$56.86	$0.65	$80.44	$70.31	$0.67
3rd Quarter	$67.37	$57.71	$0.65	$81.88	$72.93	$0.67
4th Quarter	$67.94	$60.30	$0.65	$76.03	$68.76	$0.67

On January 19, 2017, Con Edison declared a quarterly dividend of 69 cents per Common Share. The first quarter 2017 dividend will be paid on March 15, 2017.

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, see “Dividends” in Note C to the financial statements in Item 8 (which information is incorporated herein by reference).

During 2016, the market price of Con Edison’s Common Shares increased by 14.6 percent (from $64.27 at year-end 2015 to $73.68 at year-end 2016). By comparison, the S&P 500 Index increased 9.5 percent and the S&P 500 Utilities Index increased 12.2 percent. The total return to Con Edison’s common shareholders during 2016, including both price appreciation and investment of dividends, was 18.9 percent. By comparison, the total returns for the S&P 500 Index and the S&P 500 Utilities Index were 12.0 percent and 16.3 percent, respectively. For the five-year period 2012 through 2016 inclusive, Con Edison’s shareholders’ total return was 45.7 percent, compared with total returns for the S&P 500 Index and the S&P 500 Utilities Index of 98.1 percent and 63.7 percent, respectively.

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	Years Ended December 31,
Company / Index	2011	2012	2013	2014	2015	2016
Consolidated Edison, Inc.	100.00	93.28	96.81	120.82	122.52	145.73
S&P 500 Index	100.00	116.00	153.57	174.60	177.01	198.18
S&P Utilities	100.00	101.29	114.67	147.91	140.74	163.66

Based on $100 invested at December 31, 2011, reinvestment of all dividends in equivalent shares of stock and market price changes on all such shares.

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 2015 and 2016 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).

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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 “The Utilities,” “Clean Energy Businesses” and "Con Edison Transmission" in Item 1, and segment financial information in Note N to the financial statements in Item 8 and “Results of Operations,” below. Certain financial data of Con Edison’s businesses are presented below:

	For the Year Ended December 31, 2016						At December 31, 2016
(Millions of Dollars, except percentages)	Operating Revenues			Net Income			Assets
CECONY	$10,165	84	%	$1,056	85	%	$40,856	85	%
O&R	821	7	%	59	5	%	2,758	6	%
Total Utilities	10,986	91	%	1,115	90	%	43,614	91	%
Clean Energy Businesses (a)	1,091	9	%	118	9	%	2,551	5	%
Con Edison Transmission	—	—	%	20	2	%	1,150	2	%
Other (b)	(2)	—	%	(8)	(1	)%	940	2	%
Total Con Edison	$12,075	100	%	$1,245	100	%	$48,255	100	%

(a) Net income from the Clean Energy Businesses for the year ended December 31, 2016 includes $56 million of net gain related to the sale of the retail electric supply business (see Note U to the financial statements in Item 8) and $12 million of net loss related to a goodwill impairment charge on two energy services companies (see Note K to the financial statements in Item 8). Also includes for the year ended December 31, 2016, $3 million of net after-tax mark-to-market gain.

(b) Other includes parent company and consolidation adjustments.

Results of Operations

Net income and earnings per share for the years ended December 31, 2016, 2015 and 2014 were as follows:

(Millions of Dollars, except per share amounts)	Net Income			Earnings per Share
	2016	2015	2014	2016			2015			2014
CECONY	$1,056	$1,084	$1,058		$3.52			$3.70			$3.61
O&R (a)	59	52	60	0.20			0.18			0.20
Clean Energy Businesses (b)	118	59	(17)	0.39			0.20			(0.05		)
Con Edison Transmission	20	—	—	0.07			—			—
Other (c)	(8)	(2)	(9)	(0.03		)	(0.01		)	(0.03		)
Con Edison (d)	$1,245	$1,193	$1,092		$4.15			$4.07			$3.73

(a) Includes $3 million or $0.01 a share of net loss in 2015 related to the impairment of certain assets held for sale (see Note U to the financial statements in Item 8).

(b) Includes $56 million or $0.19 a share of net gain related to the sale of the retail electric supply business and $(12) million or $(0.04) a share of net loss related to the goodwill impairment charge on two energy services companies in 2016 (see Notes U and K to the financial statements in Item 8). Also includes $3 million or $0.02 a share and $(73) million or $(0.25) a share of net after-tax mark-to-market gains/(losses) in 2016 and 2014, respectively. Also includes in 2014, an after-tax gain on sale of solar electric production projects of $26 million (see Note U to the financial statements in Item 8) and an after-tax charge of $1 million relating to the LILO transactions that were terminated in 2013.

(c) Other includes parent company and consolidation adjustments.

(d) Earnings per share on a diluted basis were $4.12 a share, $4.05 a share and $3.71 a share in 2016, 2015 and 2014, respectively.

The Companies’ results of operations for 2016, as compared with 2015, and for 2015, as compared with 2014, reflect changes in the Utilities' rate plans and regulatory charges and the impact of weather on steam revenues. The results of operations also reflect higher electric retail gross profit and income from renewable investments at the Clean Energy Businesses. The rate plans provide for revenues to cover expected changes in certain operating costs including depreciation, property taxes and other tax matters.

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The following table presents the estimated effect on earnings per share and net income for 2016 as compared with 2015, and 2015 as compared with 2014, resulting from these and other major factors:

	2016 vs. 2015 Variation		2015 vs. 2014 Variation
(Millions of Dollars, except per share amounts)	Earnings per Share	Net Income	Earnings per Share	Net Income
CECONY (a)
Changes in rate plans and regulatory charges	$0.34	$96	$0.51	$147
Weather impact on steam revenues	(0.07)	(21)	(0.04)	(13)
Other operations and maintenance expenses	0.15	45	(0.02)	(5)
Depreciation, property taxes and other tax matters	(0.43)	(126)	(0.22)	(64)
Other (b)	(0.17)	(22)	(0.14)	(39)
Total CECONY	(0.18)	(28)	0.09	26
O&R (a)
Changes in rate plans and regulatory charges	—	1	0.04	13
Other operations and maintenance expenses	0.06	19	(0.03)	(9)
Depreciation and property taxes	(0.03)	(10)	(0.01)	(5)
Other (c)	(0.01)	(3)	(0.02)	(7)
Total O&R	0.02	7	(0.02)	(8)
Clean Energy Businesses
Operating revenues less energy costs	0.14	43	0.39	115
Gain on sale of retail electric supply business and solar electric production projects	0.19	56	(0.09)	(26)
Other operations and maintenance expenses	(0.06)	(18)	(0.06)	(16)
Net interest expense	(0.05)	(14)	(0.04)	(11)
Other	(0.03)	(8)	0.05	14
Total Clean Energy Businesses (d)	0.19	59	0.25	76
Con Edison Transmission	0.07	20	—	—
Other, including parent company expenses (e)	(0.02)	(6)	0.02	7
Total variations	$0.08	$52	$0.34	$101

(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 (see “Recoverable Energy Costs” in Note A and “Rate Plans” in Note B to the financial statements in Item 8). Accordingly, such costs do not generally affect the Companies’ results of operations.

(b) Includes the impact of the dilutive effect of Con Edison's stock issuances. For the year ended December 31, 2014, the variations include a sales and use tax refund received and the gain on sale of non-utility properties of $9 million or $0.03 a share and $8 million or $0.03 a share, respectively,

(c) Includes the impairment of certain assets held for sale in 2015 shown in note (a) in the Results of Operations table above.

(d) Includes the net mark-to-market effects, the gain on sale of solar electric production projects, goodwill impairment and the impact of the LILO transactions shown in note (b) in the Results of Operations table above.

(e) Reflects certain income tax benefits for Con Edison (parent company) of $7 million or $0.02 a share for the year ended December 31, 2015.

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The Companies’ other operations and maintenance expenses for the years ended December 31, 2016, 2015 and 2014 were as follows:

(Millions of Dollars)	2016	2015	2014
CECONY
Operations	$1,477	$1,464	$1,384
Pensions and other postretirement benefits	348	364	467
Health care and other benefits	160	159	149
Regulatory fees and assessments (a)	469	550	519
Other	352	344	354
Total CECONY	2,806	2,881	2,873
O&R	301	333	318
Clean Energy Businesses	164	134	108
Con Edison Transmission	3	—	—
Other (b)	(5)	(4)	(5)
Total other operations and maintenance expenses	$3,269	$3,344	$3,294

(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, 2016, 2015 and 2014 follows. For additional business segment financial information, see Note N to the financial statements in Item 8.

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Year Ended December 31, 2016 Compared with Year Ended December 31, 2015

The Companies’ results of operations in 2016 compared with 2015 were:

	CECONY			O&R			Clean Energy  Businesses			Con Edison Transmission				Other (a)				Con Edison (b)
(Millions of Dollars)	Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount		Increases (Decreases) Percent		Increases (Decreases) Amount		Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent
Operating revenues	$(163)	(1.6	)%	$(24)	(2.8	)%	$(292)	(21.1	)%		$—	—	%		$—	—		$(479)	(3.8	)%
Purchased power	(151)	(8.8	)	(13)	(6.2	)	(370)	(35.4	)	—		—		—		—		(534)	(18.0	)
Fuel	(76)	(30.6	)	—	—		—	—		—		—		—		—		(76)	(30.6	)
Gas purchased for resale	(18)	(5.3	)	(4)	(7.8	)	6	5.7		—		—		(2)		Large		(18)	(3.6	)
Other operations and maintenance	(75)	(2.6	)	(32)	(9.6	)	30	22.4		3		—		(1)		(25.0	)%	(75)	(2.2	)
Depreciation and amortization	66	6.3		(1)	(1.5	)	20	90.9		—		—		1		—		86	7.6
Taxes, other than income taxes	76	4.1		17	27.4		1	5.3		—		—		—		—		94	4.9
Gain on sale of retail electric supply business	—	—		—	—		104	—		—		—		—		—		104	—
Operating income	15	0.7		9	7.4		125	Large		(3)		—		2		Large		148	6.1
Other income less deductions	5	Large		5	Large		(12)	(35.3	)	43		—		(1)		Large		40	Large
Net interest expense	19	3.3		1	2.9		23	Large		6		—		(6)		(26.1	)	43	6.6
Income before income tax expense	1	0.1		13	15.9		90	Large		34		—		7		30.4		145	8.1
Income tax expense	29	5.1		6	20.0		31	Large		14		—		13		61.9		93	15.4
Net income	$(28)	(2.6	)%	$7	13.5	%	$59	Large		$20		—	%	$(6)		Large		$52	4.4	%

(a) Includes parent company and consolidation adjustments.

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

49

CECONY

	For the Year Ended December 31, 2016				For the Year Ended December 31, 2015
(Millions of Dollars)	Electric	Gas	Steam	2016 Total	Electric	Gas	Steam	2015 Total	2016-2015 Variation
Operating revenues	$8,106	$1,508	$551	$10,165	$8,172	$1,527	$629	$10,328	$(163)
Purchased power	1,533	—	35	1,568	1,684	—	35	1,719	(151)
Fuel	104	—	68	172	118	—	130	248	(76)
Gas purchased for resale	—	319	—	319	—	337	—	337	(18)
Other operations and maintenance	2,210	408	188	2,806	2,259	440	182	2,881	(75)
Depreciation and amortization	865	159	82	1,106	820	142	78	1,040	66
Taxes, other than income taxes	1,547	265	120	1,932	1,493	252	111	1,856	76
Operating income	$1,847	$357	$58	$2,262	$1,798	$356	$93	$2,247	$15

Electric

CECONY’s results of electric operations for the year ended December 31, 2016 compared with the year ended December 31, 2015 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	Variation
Operating revenues	$8,106	$8,172	$(66)
Purchased power	1,533	1,684	(151)
Fuel	104	118	(14)
Other operations and maintenance	2,210	2,259	(49)
Depreciation and amortization	865	820	45
Taxes, other than income taxes	1,547	1,493	54
Electric operating income	$1,847	$1,798	$49

CECONY’s electric sales and deliveries in 2016 compared with 2015 were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Years Ended							For the Years Ended
Description	December 31, 2016	December 31, 2015	Variation		Percent Variation			December 31, 2016	December 31, 2015	Variation	Percent Variation
Residential/Religious (b)	10,400	10,543	(143	)	(1.4	)%		$2,591	$2,771	$(180)	(6.5	)%
Commercial/Industrial	9,429	9,602	(173	)	(1.8	)		1,803	1,974	(171)	(8.7	)
Retail choice customers	26,813	26,662	151		0.6			2,768	2,714	54	2.0
NYPA, Municipal Agency and other sales	10,103	10,208	(105	)	(1.0	)		620	612	8	1.3
Other operating revenues (c)	—	—	—		—			324	101	223	Large
Total	56,745	57,015	(270	)	(0.5	)%	(d)	$8,106	$8,172	$(66)	(0.8	)%

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

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

(c) Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the revenue decoupling mechanism and other provisions of the company’s rate plans. See Note B to the financial statements in Item 8.

(d) After adjusting for variations, principally weather and billing days, electric delivery volumes in CECONY’s service area were the same in 2016 compared with 2015.

Operating revenues decreased $66 million in 2016 compared with 2015 due primarily to lower purchased power expenses ($151 million) and lower fuel expenses ($14 million), offset in part by higher revenues from the electric rate plan ($122 million) and changes in regulatory charges ($20 million).

Purchased power expenses decreased $151 million in 2016 compared with 2015 due to lower unit costs ($111 million) and purchased volumes ($40 million).

50

Fuel expenses decreased $14 million in 2016 compared with 2015 due to lower unit costs ($19 million), offset by higher sendout volumes from the company’s electric generating facilities ($5 million).

Other operations and maintenance expenses decreased $49 million in 2016 compared with 2015 due primarily to a decrease in the surcharges for assessments and fees that are collected in revenues from customers ($52 million) and lower uncollectible expense ($12 million), offset in part by higher costs for municipal infrastructure support ($8 million).

Depreciation and amortization increased $45 million in 2016 compared with 2015 due primarily to higher electric utility plant balances.

Taxes, other than income taxes increased $54 million in 2016 compared with 2015 due primarily to higher property taxes ($66 million), offset in part by lower state and local revenue taxes ($4 million), a favorable state audit settlement ($3 million), lower sales and use tax reserve based on a favorable audit settlement ($3 million) and lower payroll taxes ($2 million).

Gas

CECONY’s results of gas operations for the year ended December 31, 2016 compared with the year ended December 31, 2015 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	Variation
Operating revenues	$1,508	$1,527	$(19)
Gas purchased for resale	319	337	(18)
Other operations and maintenance	408	440	(32)
Depreciation and amortization	159	142	17
Taxes, other than income taxes	265	252	13
Gas operating income	$357	$356	$1

CECONY’s gas sales and deliveries, excluding off-system sales, in 2016 compared with 2015 were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Years Ended							For the Years Ended
Description	December 31, 2016	December 31, 2015	Variation		Percent Variation			December 31, 2016	December 31, 2015	Variation	Percent Variation
Residential	47,794	49,024	(1,230	)	(2.5	)%		$667	$682	$(15)	(2.2	)%
General	28,098	28,173	(75	)	(0.3	)		266	274	(8)	(2.9	)
Firm transportation	68,442	72,864	(4,422	)	(6.1	)		426	458	(32)	(7.0	)
Total firm sales and transportation	144,334	150,061	(5,727	)	(3.8	)	(b)	1,359	1,414	(55)	(3.9	)
Interruptible sales (c)	8,957	6,332	2,625		41.5			34	46	(12)	(26.1	)
NYPA	43,101	44,038	(937	)	(2.1	)		2	2	—	—
Generation plants	87,835	83,634	4,201		5.0			25	26	(1)	(3.8	)
Other	21,165	21,223	(58	)	(0.3	)		32	28	4	14.3
Other operating revenues (d)	—	—	—		—			56	11	45	Large
Total	305,392	305,288	104		—	%		$1,508	$1,527	$(19)	(1.2	)%

(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, principally weather and billing days, firm gas sales and transportation volumes in the company’s service area increased 3.9 percent in 2016 compared with 2015, reflecting primarily increased volumes attributable to additional customers that have converted from oil-to-gas as heating fuel for their buildings.

(c) Includes 4,708 thousands and 1,229 thousands of Dt for 2016 and 2015, respectively, which are also reflected in firm transportation and other.

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

Operating revenues decreased $19 million in 2016 compared with 2015 due primarily to lower gas purchased for resale expense ($18 million).

51

Gas purchased for resale decreased $18 million in 2016 compared with 2015 due to lower unit costs ($32 million), offset by higher sendout volumes ($14 million).

Other operations and maintenance expenses decreased $32 million in 2016 compared with 2015 due primarily to a decrease in the surcharges for assessments and fees that are collected in revenues from customers ($25 million), lower gas operating costs ($10 million) and lower uncollectible expense ($2 million), offset in part by higher costs for municipal infrastructure support ($5 million).

Depreciation and amortization increased $17 million in 2016 compared with 2015 due primarily to higher gas utility plant balances.

Taxes, other than income taxes increased $13 million in 2016 compared with 2015 due primarily to higher property taxes ($16 million), offset in part by lower state and local revenue taxes ($2 million).

Steam

CECONY’s results of steam operations for the year ended December 31, 2016 compared with the year ended December 31, 2015 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	Variation
Operating revenues	$551	$629	$(78)
Purchased power	35	35	—
Fuel	68	130	(62)
Other operations and maintenance	188	182	6
Depreciation and amortization	82	78	4
Taxes, other than income taxes	120	111	9
Steam operating income	$58	$93	$(35)

CECONY’s steam sales and deliveries in 2016 compared with 2015 were:

	Millions of Pounds Delivered							Revenues in Millions
	For the Years Ended							For the Years Ended
Description	December 31, 2016	December 31, 2015	Variation		Percent Variation			December 31, 2016	December 31, 2015	Variation	Percent Variation
General	465	538	(73	)	(13.6	)%		$23	$29	$(6)	(20.7	)%
Apartment house	5,792	6,272	(480	)	(7.7	)		148	176	(28)	(15.9	)
Annual power	13,722	15,109	(1,387	)	(9.2	)		378	453	(75)	(16.6	)
Other operating revenues (a)	—	—	—		—			2	(29)	31	Large
Total	19,979	21,919	(1,940	)	(8.9	)%	(b)	$551	$629	$(78)	(12.4	)%

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

(b) After adjusting for variations, principally weather and billing days, steam sales and deliveries decreased 1.2 percent in 2016 compared with 2015.

Operating revenues decreased $78 million in 2016 compared with 2015 due primarily to lower fuel expenses ($62 million) and the weather impact on revenues ($35 million), offset in part by higher revenues from the steam rate plan ($22 million).

Fuel expenses decreased $62 million in 2016 compared with 2015 due to lower unit costs ($57 million) and sendout volumes ($5 million).

Other operations and maintenance expenses increased $6 million in 2016 compared with 2015 due primarily to higher costs for municipal infrastructure support.

Depreciation and amortization increased $4 million in 2016 compared with 2015 due primarily to higher steam utility plant balances.

Taxes, other than income taxes increased $9 million in 2016 compared with 2015 due primarily to higher property taxes ($12 million), offset in part by lower state and local revenue taxes ($2 million).

52

Taxes, Other Than Income Taxes

At $1.9 billion, 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)	2016		2015		Variation
Property taxes	$1,557		$1,463		$94
State and local taxes related to revenue receipts	315		323		(8)
Payroll taxes	65		67		(2)
Other taxes	(5)		3		(8)
Total	$1,932	(a)	$1,856	(a)	$76

(a) Including sales tax on customers’ bills, total taxes other than income taxes in 2016 and 2015 were $2,358 million and $2,302 million, respectively.

Other Income (Deductions)

Other income (deductions) increased $5 million in 2016 compared with 2015 due primarily to an increase in the allowance for equity funds used during construction ($4 million).

Net Interest Expense

Net interest expense increased $19 million in 2016 compared with 2015 due primarily to new debt issuances in 2016.

Income Tax Expense

Income taxes increased $29 million in 2016 compared with 2015 due primarily to plant-related flow through items ($57 million) and an increase in uncertain tax positions ($2 million), offset in part by lower state income taxes ($15 million) and higher research and development tax credits ($14 million).

O&R

	For the Year Ended December 31, 2016			For the Year Ended December 31, 2015
(Millions of Dollars)	Electric	Gas	2016 Total	Electric	Gas	2015 Total	2016-2015 Variation
Operating revenues	$637	$184	$821	$663	$182	$845	$(24)
Purchased power	197	—	197	210	—	210	(13)
Gas purchased for resale	—	47	47	—	51	51	(4)
Other operations and maintenance	244	57	301	256	77	333	(32)
Depreciation and amortization	49	18	67	50	18	68	(1)
Taxes, other than income taxes	52	27	79	44	18	62	17
Operating income	$95	$35	$130	$103	$18	$121	$9

Electric

O&R’s results of electric operations for the year ended December 31, 2016 compared with the year ended December 31, 2015 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	Variation
Operating revenues	$637	$663	$(26)
Purchased power	197	210	(13)
Other operations and maintenance	244	256	(12)
Depreciation and amortization	49	50	(1)
Taxes, other than income taxes	52	44	8
Electric operating income	$95	$103	$(8)

53

O&R’s electric sales and deliveries in 2016 compared with 2015 were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Years Ended							For the Years Ended
Description	December 31, 2016	December 31, 2015	Variation		Percent Variation			December 31, 2016	December 31, 2015	Variation	Percent Variation
Residential/Religious (b)	1,654	1,597	57		3.6	%		$304	$307	$(3)	(1.0	)%
Commercial/Industrial	801	802	(1	)	(0.1	)		114	124	(10)	(8.1	)
Retail choice customers	3,180	3,237	(57	)	(1.8	)		213	213	—	—
Public authorities	100	100	—		—			8	10	(2)	(20.0	)
Other operating revenues (c)	—	—	—		—			(2)	9	(11)	Large
Total	5,735	5,736	(1	)	—	%	(d)	$637	$663	$(26)	(3.9	)%

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

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

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

(d) After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased 0.9 percent in 2016 compared with 2015.

Operating revenues decreased $26 million in 2016 compared with 2015 due primarily to lower purchased power expenses ($13 million) and lower revenues from the New York electric rate plan (which includes the reconciliation of certain expenses, see Note B to the financial statements in Item 8) ($7 million).

Purchased power expenses decreased $13 million in 2016 compared with 2015 due to a decrease in unit costs ($18 million), offset by an increase in purchased volumes ($5 million).

Other operations and maintenance expenses decreased $12 million in 2016 compared with 2015 due primarily to regulatory accounting effects of pension costs ($11 million) and the charge-off of certain regulatory assets in 2015 ($4 million), offset by higher operating costs ($3 million).

Depreciation and amortization decreased $1 million in 2016 compared with 2015 due primarily to lower average depreciation rates.

Taxes, other than income taxes increased $8 million in 2016 compared with 2015 due primarily to higher property taxes.

Gas

O&R’s results of gas operations for the year ended December 31, 2016 compared with the year ended December 31, 2015 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	Variation
Operating revenues	$184	$182	$2
Gas purchased for resale	47	51	(4)
Other operations and maintenance	57	77	(20)
Depreciation and amortization	18	18	—
Taxes, other than income taxes	27	18	9
Gas operating income	$35	$18	$17

54

O&R’s gas sales and deliveries, excluding off-system sales, in 2016 compared with 2015 were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Years Ended							For the Years Ended
Description	December 31, 2016	December 31, 2015	Variation		Percent Variation			December 31, 2016	December 31, 2015	Variation	Percent Variation
Residential	7,872	7,664	208		2.7	%		$84	$77	$7	9.1	%
General	1,851	1,684	167		9.9			15	14	1	7.1
Firm transportation	10,381	11,752	(1,371	)	(11.7	)		70	68	2	2.9
Total firm sales and transportation	20,104	21,100	(996	)	(4.7	)	(b)	169	159	10	6.3
Interruptible sales	3,853	4,205	(352	)	(8.4	)		3	3	—	—
Generation plants	18	25	(7	)	(28.0	)		—	—	—	—
Other	867	906	(39	)	(4.3	)		—	—	—	—
Other gas revenues	—	—	—		—			12	20	(8)	(40.0	)
Total	24,842	26,236	(1,394	)	(5.3	)%		$184	$182	$2	1.1	%

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

(b) After adjusting for weather and other variations, total firm sales and transportation volumes increased 2.3 percent in 2016 compared with 2015.

Operating revenues increased $2 million in 2016 compared with 2015 due primarily to higher revenues from the New York gas rate plan ($9 million), offset in part by the decrease in gas purchased for resale ($4 million).

Gas purchased for resale decreased $4 million in 2016 compared with 2015 due to a decrease in purchased volumes ($5 million), offset by an increase in unit costs ($1 million).

Other operations and maintenance expenses decreased $20 million in 2016 compared with 2015 due primarily to the charge-off of certain regulatory assets in 2015 ($14 million) and regulatory accounting effects of pension costs ($10 million), offset by higher operating costs ($4 million).

Taxes, other than income taxes increased $9 million in 2016 compared with 2015 due primarily to higher property taxes.

Taxes, Other Than Income Taxes

Taxes, other than income taxes, increased $17 million in 2016 compared with 2015. The principal components of taxes, other than income taxes, were:

	For the Years Ended December 31,
(Millions of Dollars)	2016		2015		Variation
Property taxes	$63		$46		$17
State and local taxes related to revenue receipts	10		10		—
Payroll taxes	6		6		—
Total	$79	(a)	$62	(a)	$17

(a) Including sales tax on customers’ bills, total taxes other than income taxes in 2016 and 2015 were $105 million and $88 million, respectively.

Other Income (Deductions)

Other income (deductions) increased $5 million in 2016 compared with 2015 due primarily to the impairment of certain assets held for sale in 2015 (see Note U to the financial statements in Item 8).

Income Tax Expense

Income taxes increased $6 million in 2016 compared with 2015 due primarily to higher income before income tax expense ($5 million) and plant-related flow through items ($3 million), offset in part by lower taxable reimbursement in insurance claims ($1 million) and a higher tax benefit from a corporate-owned life insurance policy ($1 million).

55

Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the year ended December 31, 2016 compared with the year ended December 31, 2015 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	Variation
Operating revenues	$1,091	$1,383	$(292)
Purchased power	674	1,044	(370)
Gas purchased for resale	112	106	6
Other operations and maintenance	164	134	30
Depreciation and amortization	42	22	20
Taxes, other than income taxes	20	19	1
Gain on sale of retail electric supply business	104	—	104
Operating income	$183	$58	$125

Operating revenues decreased $292 million in 2016 compared with 2015 due primarily to lower electric retail revenues. Electric retail revenues decreased $389 million in 2016 as compared with 2015 due to the sale of the retail electric supply business (see Note U to the financial statements in Item 8). Solar revenues increased $54 million in 2016 as compared with 2015 due primarily to an increase in solar electric production projects in operation. Energy services revenues increased $41 million due to an increase in active projects. Wholesale revenues increased $8 million in 2016 compared with 2015 due primarily to higher sales volumes. Net mark-to-market values increased $6 million in 2016 as compared with 2015, of which $12 million in gains are reflected in purchased power expenses and $6 million in losses are reflected in revenues.

Purchased power expenses decreased $370 million in 2016 compared with 2015 due to the sale of the retail electric supply business ($373 million) (see Note U to the financial statements in Item 8) and changes in mark-to-market gains ($12 million).

Gas purchased for resale increased $6 million in 2016 compared with 2015 due primarily to higher sales volumes.

Other operations and maintenance expenses increased $30 million in 2016 compared with 2015 due primarily to an increase in energy services costs ($28 million) and other general operating expenses ($2 million).

Depreciation and amortization increased $20 million in 2016 compared with 2015 due primarily to an increase in renewable electric production projects in operation during 2016.

Taxes, other than income taxes increased $1 million in 2016 compared with 2015 due primarily to higher property taxes ($5 million), offset by lower gross receipt taxes ($4 million).

Gain on sale of retail electric supply business was $104 million in 2016 reflecting the sale of the retail electric supply business (see Note U to the financial statements in Item 8).

Other Income (Deductions)

Other income (deductions) decreased $12 million in 2016 compared with 2015 due primarily to the impairment of goodwill ($15 million) (see Note K to the financial statements in Item 8), offset in part by income from solar electric production investments ($3 million).

Net Interest Expense

Net interest expense increased $23 million in 2016 compared with 2015 due primarily to new debt issuances for renewable electric production projects.

Income Tax Expense

Income taxes increased $31 million in 2016 compared with 2015 due primarily to higher income before income tax expense ($38 million), an increase to deferred state income taxes as a result of the sale of the retail electric supply business ($4 million) and an increase in valuation allowances against state net operating loss carryforwards ($3 million), offset in part by higher production tax credits ($10 million) and the reversal of uncertain tax positions ($4 million).

56

Con Edison Transmission

Other Income (Deductions)

Other income (deductions) increased $43 million in 2016 compared with 2015 due primarily to earnings from equity investments in 2016 (see Note U to the financial statements in Item 8).

Income Tax Expense

Income taxes increased $14 million in 2016 compared with 2015 due primarily to higher income before income tax expense.

Other

For Con Edison, “Other” also includes intercompany eliminations relating to operating revenues and operating expenses.

Year Ended December 31, 2015 Compared with Year Ended December 31, 2014

The Companies’ results of operations in 2015 compared with 2014 were:

	CECONY			O&R			Clean Energy Businesses (a)			Other (b)			Con Edison (c)
(Millions of Dollars)	Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent
Operating revenues	$(458)	(4.2	)%	$(47)	(5.3	)%	$139	11.2	%	$1	33.3	%	$(365)	(2.8	)%
Purchased power	(372)	(17.8	)	(28)	(11.8	)	(44)	(4.0	)	—	—		(444)	(13.0	)
Fuel	(37)	(13.0	)	—	—		—	—		—	—		(37)	(13.0	)
Gas purchased for resale	(272)	(44.7	)	(37)	(42.0	)	(9)	(7.8	)	2	Large		(316)	(39.0	)
Other operations and maintenance	8	0.3		15	4.7		26	24.1		1	20.0		50	1.5
Depreciation and amortization	49	4.9		7	11.5		3	15.8		—	—		59	5.5
Taxes, other than income taxes	58	3.2		2	3.3		—	—		—	—		60	3.2
Gain on sale of solar electric production projects	—	—		—	—		(45)	—		—	—		(45)	—
Operating income (loss)	108	5.0		(6)	(4.7	)	118	Large		(2)	(66.7	)	218	9.9
Other income less deductions	(16)	Large		(7)	Large		6	21.4		(1)	—		(18)	(42.9	)
Net interest expense	47	8.8		—	—		19	Large		(4)	(14.8	)	62	10.5
Income before income tax expense	45	2.8		(13)	(13.7	)	105	Large		1	4.2		138	8.3
Income tax expense	19	3.4		(5)	(14.3	)	29	Large		(6)	(40.0	)	37	6.5
Net income	$26	2.5	%	$(8)	(13.3	)%	$76	Large		$7	77.8	%	$101	9.2	%

(a) See “Overview - Clean Energy Businesses” in Item 1.

(b) Includes parent company and consolidation adjustments.

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

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CECONY

	For the Year Ended December 31, 2015				For the Year Ended December 31, 2014
(Millions of Dollars)	Electric	Gas	Steam	2015 Total	Electric	Gas	Steam	2014 Total	2015-2014 Variation
Operating revenues	$8,172	$1,527	$629	$10,328	$8,437	$1,721	$628	$10,786	$(458)
Purchased power	1,684	—	35	1,719	2,036	—	55	2,091	(372)
Fuel	118	—	130	248	180	—	105	285	(37)
Gas purchased for resale	—	337	—	337	—	609	—	609	(272)
Other operations and maintenance	2,259	440	182	2,881	2,270	418	185	2,873	8
Depreciation and amortization	820	142	78	1,040	781	132	78	991	49
Taxes, other than income taxes	1,493	252	111	1,856	1,458	248	92	1,798	58
Operating income	$1,798	$356	$93	$2,247	$1,712	$314	$113	$2,139	$108

Electric

CECONY’s results of electric operations for the year ended December 31, 2015 compared with the year ended December 31, 2014 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2015	2014	Variation
Operating revenues	$8,172	$8,437	$(265)
Purchased power	1,684	2,036	(352)
Fuel	118	180	(62)
Other operations and maintenance	2,259	2,270	(11)
Depreciation and amortization	820	781	39
Taxes, other than income taxes	1,493	1,458	35
Electric operating income	$1,798	$1,712	$86

CECONY’s electric sales and deliveries in 2015 compared with 2014 were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Years Ended							For the Years Ended
Description	December 31, 2015	December 31, 2014	Variation		Percent Variation			December 31, 2015	December 31, 2014	Variation	Percent Variation
Residential/Religious (b)	10,543	9,868	675		6.8	%		$2,771	$2,847	$(76)	(2.7	)%
Commercial/Industrial	9,602	9,834	(232	)	(2.4	)		1,974	2,176	(202)	(9.3	)
Retail choice customers	26,662	26,221	441		1.7			2,714	2,646	68	2.6
NYPA, Municipal Agency and other sales	10,208	10,380	(172	)	(1.7	)		612	625	(13)	(2.1	)
Other operating revenues (c)	—	—	—		—			101	143	(42)	(29.4	)
Total	57,015	56,303	712		1.3	%	(d)	$8,172	$8,437	$(265)	(3.1	)%

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

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

(c) Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the revenue decoupling mechanism and other provisions of the company’s rate plans. See Note B to the financial statements in Item 8.

(d) After adjusting for variations, principally weather and billing days, electric delivery volumes in CECONY’s service area decreased 0.9 percent in 2015 compared with 2014.

Operating revenues decreased $265 million in 2015 compared with 2014 due primarily to lower purchased power expenses ($352 million) and lower fuel expenses ($62 million), offset in part by higher revenues from the electric rate plan ($156 million).

Purchased power expenses decreased $352 million in 2015 compared with 2014 due to a decrease in unit costs ($381 million), offset by an increase in purchased volumes ($29 million).

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Fuel expenses decreased $62 million in 2015 compared with 2014 due to lower unit costs ($69 million), offset by higher sendout volumes from the company’s electric generating facilities ($7 million).

Other operations and maintenance expenses decreased $11 million in 2015 compared with 2014 due primarily to lower pension costs ($85 million), offset in part by an increase in the surcharges for assessments and fees that are collected in revenues from customers ($44 million) and higher electric operating costs ($23 million).

Depreciation and amortization increased $39 million in 2015 compared with 2014 due primarily to higher electric utility plant balances.

Taxes, other than income taxes increased $35 million in 2015 compared with 2014 due primarily to higher property taxes ($31 million) and a sales and use tax refund received in 2014 ($12 million), offset in part by the elimination of the New York City subsidiary capital tax ($6 million) and lower state and local revenue taxes ($3 million).

Gas

CECONY’s results of gas operations for the year ended December 31, 2015 compared with the year ended December 31, 2014 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2015	2014	Variation
Operating revenues	$1,527	$1,721	$(194)
Gas purchased for resale	337	609	(272)
Other operations and maintenance	440	418	22
Depreciation and amortization	142	132	10
Taxes, other than income taxes	252	248	4
Gas operating income	$356	$314	$42

CECONY’s gas sales and deliveries, excluding off-system sales, in 2015 compared with 2014 were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Years Ended							For the Years Ended
Description	December 31, 2015	December 31, 2014	Variation		Percent Variation			December 31, 2015	December 31, 2014	Variation	Percent Variation
Residential	49,024	46,661	2,363		5.1	%		$682	$782	$(100)	(12.8	)%
General	28,173	28,969	(796	)	(2.7	)		274	359	(85)	(23.7	)
Firm transportation	72,864	68,731	4,133		6.0			458	453	5	1.1
Total firm sales and transportation	150,061	144,361	5,700		3.9		(b)	1,414	1,594	(180)	(11.3	)
Interruptible sales (c)	6,332	10,498	(4,166	)	(39.7	)		46	91	(45)	(49.5	)
NYPA	44,038	47,548	(3,510	)	(7.4	)		2	2	—	—
Generation plants	83,634	82,146	1,488		1.8			26	30	(4)	(13.3	)
Other	21,223	22,866	(1,643	)	(7.2	)		28	40	(12)	(30.0	)
Other operating revenues (d)	—	—	—		—			11	(36)	47	Large
Total	305,288	307,419	(2,131	)	(0.7	)%		$1,527	$1,721	$(194)	(11.3	)%

(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, principally weather and billing days, firm gas sales and transportation volumes in the company’s service area increased 6.7 percent in 2015 compared with 2014, reflecting primarily increased volumes attributable to additional customers that have converted from oil-to-gas as heating fuel for their buildings.

(c) Includes 1,229 and 6,057 thousands of Dt for 2015 and 2014, respectively, which are also reflected in firm transportation and other.

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

Operating revenues decreased $194 million in 2015 compared with 2014 due primarily to a decrease in gas purchased for resale expenses ($272 million), offset in part by higher revenues from the gas rate plan ($77 million) reflecting primarily higher delivery volumes attributable to oil-to-gas conversions.

Gas purchased for resale decreased $272 million in 2015 compared with 2014 due to lower unit costs ($274 million), offset by higher sendout volumes ($2 million).

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Other operations and maintenance expenses increased $22 million in 2015 compared with 2014 due primarily to higher operating costs attributable to emergency response ($45 million), offset in part by lower pension costs ($12 million) and a decrease in the surcharges for assessments and fees that are collected in revenues from customers ($10 million). Other operations and maintenance expenses for emergency response activities in 2015 and 2014 were above amounts for such costs reflected in the company’s gas rate plan. The company has requested NYSPSC authorization to defer for recovery as a regulatory asset $29 million and $35 million of such incremental costs incurred in 2014 and 2015, respectively. The company anticipates requesting deferral of 2016 incremental costs in 2017. At December 31, 2015, the company had not deferred any such incremental costs.

Depreciation and amortization increased $10 million in 2015 compared with 2014 due primarily to higher gas utility plant balances.

Taxes, other than income taxes increased $4 million in 2015 compared with 2014 due primarily to higher property taxes ($8 million) and a sales and use tax refund received in 2014 ($2 million), offset in part by lower state and local revenue taxes ($6 million).

Steam

CECONY’s results of steam operations for the year ended December 31, 2015 compared with the year ended December 31, 2014 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2015	2014	Variation
Operating revenues	$629	$628	$1
Purchased power	35	55	(20)
Fuel	130	105	25
Other operations and maintenance	182	185	(3)
Depreciation and amortization	78	78	—
Taxes, other than income taxes	111	92	19
Steam operating income	$93	$113	$(20)

CECONY’s steam sales and deliveries in 2015 compared with 2014 were:

	Millions of Pounds Delivered							Revenues in Millions
	For the Years Ended							For the Years Ended
Description	December 31, 2015	December 31, 2014	Variation		Percent Variation			December 31, 2015	December 31, 2014	Variation	Percent Variation
General	538	594	(56	)	(9.4	)%		$29	$30	$(1)	(3.3	)%
Apartment house	6,272	6,574	(302	)	(4.6	)		176	180	(4)	(2.2	)
Annual power	15,109	15,848	(739	)	(4.7	)		453	469	(16)	(3.4	)
Other operating revenues (a)	—	—	—		—			(29)	(51)	22	43.1
Total	21,919	23,016	(1,097	)	(4.8	)%	(b)	$629	$628	$1	0.2	%

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

(b) After adjusting for variations, principally weather and billing days, steam sales and deliveries decreased 2.1 percent in 2015 compared with 2014.

Operating revenues increased $1 million in 2015 compared with 2014 due primarily to higher fuel expenses ($25 million) and higher revenues from the steam rate plan ($13 million), offset in part by the weather impact on revenues ($21 million) and lower purchased power costs ($20 million).

Purchased power expenses decreased $20 million in 2015 compared with 2014 due to a decrease in unit costs ($18 million) and purchased volumes ($2 million).

Fuel expenses increased $25 million in 2015 compared with 2014 due to higher unit costs ($33 million), offset by lower sendout volumes ($8 million).

Other operations and maintenance expenses decreased $3 million in 2015 compared with 2014 due primarily to a decrease in the surcharges for assessments and fees that are collected in revenues from customers.

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Taxes, other than income taxes increased $19 million in 2015 compared with 2014 due primarily to higher property taxes ($18 million) and a sales and use tax refund received in 2014 ($1 million).

Taxes, Other Than Income Taxes

At $1.9 billion, 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)	2015		2014		Variation
Property taxes	$1,463		$1,406		$57
State and local taxes related to revenue receipts	323		332		(9)
Payroll taxes	67		65		2
Other taxes	3		(5)	(a)	8
Total	$1,856	(b)	$1,798	(b)	$58

(a) Includes a sales and use tax refund of $15 million.

(b) Including sales tax on customers’ bills, total taxes other than income taxes in 2015 and 2014 were $2,302 million and $2,267 million, respectively.

Other Income (Deductions)

Other income (deductions) decreased $16 million in 2015 compared with 2014 due primarily to the gain on sale of certain non-utility properties in 2014.

Net Interest Expense

Net interest expense increased $47 million in 2015 compared with 2014 due primarily to new debt issuances in late 2014.

Income Tax Expense

Income taxes increased $19 million in 2015 compared with 2014 due primarily to higher income before income tax expense.

O&R

	For the Year Ended December 31, 2015			For the Year Ended December 31, 2014
(Millions of Dollars)	Electric	Gas	2015 Total	Electric	Gas	2014 Total	2015-2014 Variation
Operating revenues	$663	$182	$845	$680	$212	$892	$(47)
Purchased power	210	—	210	238	—	238	(28)
Gas purchased for resale	—	51	51	—	88	88	(37)
Other operations and maintenance	256	77	333	251	67	318	15
Depreciation and amortization	50	18	68	46	15	61	7
Taxes, other than income taxes	44	18	62	43	17	60	2
Operating income	$103	$18	$121	$102	$25	$127	$(6)

Electric

O&R’s results of electric operations for the year ended December 31, 2015 compared with the year ended December 31, 2014 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2015	2014	Variation
Operating revenues	$663	$680	$(17)
Purchased power	210	238	(28)
Other operations and maintenance	256	251	5
Depreciation and amortization	50	46	4
Taxes, other than income taxes	44	43	1
Electric operating income	$103	$102	$1

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O&R’s electric sales and deliveries in 2015 compared with 2014 were:

	Millions of kWh Delivered							Revenues in Millions (a)
	For the Years Ended							For the Years Ended
Description	December 31, 2015	December 31, 2014	Variation		Percent Variation			December 31, 2015	December 31, 2014	Variation	Percent Variation
Residential/Religious (b)	1,597	1,515	82		5.4	%		$307	$307	—	—
Commercial/Industrial	802	812	(10	)	(1.2	)		124	136	$(12)	(8.8	)%
Retail choice customers	3,237	3,240	(3	)	(0.1	)		213	207	6	2.9
Public authorities	100	102	(2	)	(2.0	)		10	12	(2)	(16.7	)
Other operating revenues (c)	—	—	—		—			9	18	(9)	(50.0	)
Total	5,736	5,669	67		1.2	%	(d)	$663	$680	$(17)	(2.5	)%

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

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

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

(d) After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased.0.9 percent in 2015 compared with 2014.

Operating revenues decreased $17 million in 2015 compared with 2014 due primarily to lower purchased power expenses ($28 million), offset in part by higher revenues from the New York electric rate plan ($19 million).

Purchased power expenses decreased $28 million in 2015 compared with 2014 due to a decrease in unit costs ($24 million) and purchased volumes ($4 million).

Other operations and maintenance expenses increased $5 million in 2015 compared with 2014 due primarily to the charge-off of certain regulatory assets ($4 million) and an increase in surcharges for assessments and fees that are collected in revenues from customers ($1 million).

Depreciation and amortization increased $4 million in 2015 compared with 2014 due primarily to higher electric utility plant balances.

Taxes, other than income taxes increased $1 million in 2015 compared with 2014 due primarily to higher property taxes and state and local revenue taxes.

Gas

O&R’s results of gas operations for the year ended December 31, 2015 compared with the year ended December 31, 2014 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2015	2014	Variation
Operating revenues	$182	$212	$(30)
Gas purchased for resale	51	88	(37)
Other operations and maintenance	77	67	10
Depreciation and amortization	18	15	3
Taxes, other than income taxes	18	17	1
Gas operating income	$18	$25	$(7)

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O&R’s gas sales and deliveries, excluding off-system sales, in 2015 compared with 2014 were:

	Thousands of Dt Delivered							Revenues in Millions (a)
	For the Years Ended							For the Years Ended
Description	December 31, 2015	December 31, 2014	Variation		Percent Variation			December 31, 2015	December 31, 2014	Variation	Percent Variation
Residential	7,664	7,786	(122	)	(1.6	)%		$77	$101	$(24)	(23.8	)%
General	1,684	1,743	(59	)	(3.4	)		14	20	(6)	(30.0	)
Firm transportation	11,752	12,592	(840	)	(6.7	)		68	75	(7)	(9.3	)
Total firm sales and transportation	21,100	22,121	(1,021	)	(4.6	)	(b)	159	196	(37)	(18.9	)
Interruptible sales	4,205	4,216	(11	)	(0.3	)		3	2	1	50.0
Generation plants	25	70	(45	)	(64.3	)		—	1	(1)	Large
Other	906	945	(39	)	(4.1	)		—	—	—	—
Other gas revenues	—	—	—		—			20	13	7	53.8
Total	26,236	27,352	(1,116	)	(4.1	)%		$182	$212	$(30)	(14.2	)%

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

(b) After adjusting for weather and other variations, total firm sales and transportation volumes increased 1.7 percent in 2015 compared with 2014.

Operating revenues decreased $30 million in 2015 compared with 2014 due primarily to the decrease in gas purchased for resale ($37 million), offset in part by higher revenues from the gas rate plan ($3 million).

Gas purchased for resale decreased $37 million in 2015 compared with 2014 due to a decrease in unit costs ($30 million) and purchased volumes ($7 million).

Other operations and maintenance expenses increased $10 million in 2015 compared with 2014 due primarily to the charge-off of certain regulatory assets ($14 million), offset in part by lower pension costs ($2 million).

Depreciation and amortization increased $3 million in 2015 compared with 2014 due primarily to higher gas utility plant balances.

Taxes, other than income taxes increased $1 million in 2015 compared with 2014 due primarily to higher property taxes.

Taxes, Other Than Income Taxes

Taxes, other than income taxes, increased $2 million in 2015 compared with 2014. The principal components of taxes, other than income taxes, were:

	For the Years Ended December 31,
(Millions of Dollars)	2015		2014		Variation
Property taxes	$46		$44		$2
State and local taxes related to revenue receipts	10		9		1
Payroll taxes	6		7		(1)
Total	$62	(a)	$60	(a)	$2

(a) Including sales tax on customers’ bills, total taxes other than income taxes in 2015 and 2014 were $88 million and $86 million, respectively.

Other Income (Deductions)

Other income (deductions) decreased $7 million in 2015 compared with 2014 due primarily to the impairment of Pike assets held for sale (see Note U to the financial statements in Item 8).

Income Tax Expense

Income taxes decreased $5 million in 2015 compared with 2014 due primarily to lower income before income tax expense.

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Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the year ended December 31, 2015 compared with the year ended December 31, 2014 is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2015	2014	Variation
Operating revenues	$1,383	$1,244	$139
Purchased power	1,044	1,088	(44)
Gas purchased for resale	106	115	(9)
Other operations and maintenance	134	108	26
Depreciation and amortization	22	19	3
Taxes, other than income taxes	19	19	—
(Gain) on sale of solar electric production projects	—	(45)	45
Operating income (loss)	$58	$(60)	$118

Operating revenues increased $139 million in 2015 compared with 2014 due primarily to higher electric retail revenues. Electric retail revenues increased $158 million in 2015 as compared with 2014 due to higher sales volume ($163 million), offset by lower unit prices ($5 million). Wholesale revenues decreased $33 million in 2015 compared with 2014 due primarily to lower sales volumes. Solar revenues increased $12 million in 2015 as compared with 2014 due primarily to an increase in solar electric production projects in operation. Net mark-to-market values increased $128 million in 2015 as compared with 2014, of which $131 million in gains are reflected in purchased power expenses and $3 million in losses are reflected in revenues. Other revenues increased $5 million in 2015 as compared with 2014, due primarily to higher energy services revenues.

Purchased power expenses decreased $44 million in 2015 compared with 2014 due to changes in mark-to-market gains ($131 million) and lower unit prices ($45 million), offset by higher volumes ($132 million).

Gas purchased for resale decreased $9 million in 2015 compared with 2014 due primarily to lower volumes.

Other operations and maintenance expenses increased $26 million in 2015 compared with 2014 due primarily to an increase in energy services costs ($11 million), other general operating expenses ($11 million) and business development costs ($4 million).

Depreciation and amortization expense increased $3 million in 2015 compared with 2014 due primarily to an increase in solar electric production projects in operation during 2015.

Gain on sale of solar electric production projects decreased $45 million reflecting the May 2014 sale by Con Edison Development of 50 percent of its membership interest in California Solar (see Note Q to the financial statements in Item 8).

Other Income (Deductions)

Other income (deductions) increased $6 million in 2015 compared to 2014 primarily reflecting income from renewable electric production projects accounted for under the equity method.

Net Interest Expense

Net interest expense increased $19 million in 2015 compared to 2014 due primarily to adjustments in 2014 to accrued interest on taxes relating to the LILO transactions which were terminated in 2013.

Income Tax Expense

Income taxes increased $29 million in 2015 compared with 2014 due primarily to higher income before income tax expense, offset in part by higher production tax credits ($5 million) and amortization of investment tax credits ($4 million) in 2015.

Other

For Con Edison, “Other” also includes intercompany eliminations relating to operating revenues and operating expenses.

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Liquidity and Capital Resources

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

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” and “The Companies Also Face Other Risks That Are Beyond Their Control” in Item 1A, and “Capital Requirements and Resources” in Item 1.

Changes in the Companies’ cash and temporary cash investments resulting from operating, investing and financing activities for the years ended December 31, 2016, 2015 and 2014 are summarized as follows:

Con Edison

(Millions of Dollars)	2016	2015	Variance 2016 vs. 2015	2014	Variance 2015 vs. 2014
Operating activities	$3,459	$3,277	$182	$2,831	$446
Investing activities	(4,976)	(3,657)	(1,319)	(2,759)	(898)
Financing activities	1,345	629	716	(47)	676
Net change for the period	(172)	249	(421)	25	224
Balance at beginning of period	944	699	245	674	25
Balance at end of period	772	948	(176)	699	249
Less: Change in cash balances held for sale	(4)	4	(8)	—	4
Balance at end of period excluding held for sale	$776	$944	$(168)	$699	$245

CECONY

(Millions of Dollars)	2016	2015	Variance 2016 vs. 2015	2014	Variance 2015 vs. 2014
Operating activities	$3,038	$2,819	$219	$2,430	$389
Investing activities	(2,739)	(2,638)	(101)	(2,304)	(334)
Financing activities	(440)	17	(457)	(114)	131
Net change for the period	(141)	198	(339)	12	186
Balance at beginning of period	843	645	198	633	12
Balance at end of period	$702	$843	$(141)	$645	$198

Cash Flows from Operating Activities

The Utilities’ cash flows from operating activities reflect principally their energy sales and deliveries and cost of operations. The volume of energy sales and deliveries is affected primarily 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 "Utility Regulation - State Utility Regulation - New York Utility Industry - Reforming the Energy Vision," "Competition" and "Environmental Matters - Climate Change" in Item 1. 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

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income. See Note B to the financial statements in Item 8. 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.

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 and amortizations of certain regulatory assets and liabilities. 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 O&R – Electric and Gas” in Note B to the financial statements in Item 8.

Net cash flows from operating activities in 2016 for Con Edison and CECONY were $182 million and $219 million higher, respectively, than in 2015. The increase in net cash flows for Con Edison and CECONY reflects primarily lower income taxes paid, net of refunds received in 2016 as compared with 2015 ($144 million and $325 million, respectively), offset by higher interest payments ($67 million and $27 million, respectively) in 2016. The amount and timing of income tax payments and refunds received reflect, among other things, the extension of bonus depreciation tax provisions. See Note L to the financial statements in Item 8.

Net cash flows from operating activities in 2015 for Con Edison and CECONY were $446 million and $389 million higher, respectively, than in 2014. The increase in net cash flows for Con Edison and CECONY reflects primarily lower income taxes paid, net of refunds received in 2015 ($669 million and $585 million, respectively), offset in part by increased pension contributions ($172 million and $159 million, respectively) in 2015. The amount and timing of income tax payments and refunds received reflect, among other things, the extension of bonus depreciation tax provisions. See Note L to the financial statements in Item 8. For information about the Companies' pension contributions, see Note E to the financial statements in Item 8.

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 energy costs and accounts payable balances.

The changes in regulatory assets principally reflect changes in deferred pension costs in accordance with the accounting rules for retirement benefits. See Notes A, B and E to the financial statements in Item 8.

Cash Flows Used in Investing Activities

Net cash flows used in investing activities for Con Edison and CECONY were $1,319 million and $101 million higher, respectively, in 2016 than in 2015. The change for Con Edison reflects primarily increased investments in/acquisitions of electric and gas transmission projects ($1,076 million), increased utility construction expenditures in 2016 ($273 million) and increased non-utility construction expenditures related to development of renewable electric production projects ($353 million), offset in part by the proceeds from the sale and transfer of assets ($374 million). The change for CECONY reflects primarily increased utility construction expenditures in 2016 ($262 million), offset in part by the proceeds from the transfer of assets to NY Transco ($122 million).

Net cash flows used in investing activities for Con Edison and CECONY were $898 million and $334 million higher, respectively, in 2015 than in 2014. The changes for Con Edison and CECONY reflect increased utility construction expenditures in 2015 ($323 million and $316 million, respectively). In addition, the change for Con Edison reflects primarily increased non-utility construction expenditures related to renewable electric production projects ($312 million), the proceeds from sale relating to its solar electric production projects in 2014 ($108 million, see Note Q to the financial statements in Item 8) and increased other investing activities ($82 million, representing primarily a note receivable related to Panoche Valley, see Note Q to the financial statements in Item 8).

Cash Flows From Financing Activities

Net cash flows from financing activities in 2016 for Con Edison and CECONY were $716 million higher and $457 million lower, respectively, than in 2015. Net cash flows from financing activities in 2015 for Con Edison and CECONY were $676 million and $131 million higher, respectively, than in 2014.

Net cash flows from financing activities during the year ended December 31, 2016 reflect the following Con Edison transactions:

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2016

• Borrowed $400 million pursuant to a credit agreement with a syndicate of banks, the net proceeds from the borrowing of which were used for general corporate purposes. The borrowing matures in 2018 and bears interest at a rate of LIBOR plus 1.00 percent;

• Issued approximately 10 million common shares resulting in net proceeds, after issuance expenses, of $702 million and $500 million of 2.00 percent debentures, due 2021, the net proceeds from the sale of which were used in connection with the acquisition by a CET Gas subsidiary of a 50 percent equity interest in a gas pipeline and storage joint venture (see "Con Edison Transmission" in Item 1) and for general corporate purposes.

Con Edison had no issuances of long-term debt in 2015 or 2014.

Con Edison’s cash flows from financing activities in 2016, 2015 and 2014 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 $97 million, $29 million and $1 million, respectively, net of repurchases in 2015 and 2014.

Net cash flows from financing activities during the years ended December 31, 2016, 2015 and 2014 reflect the following CECONY transactions:

2016

• Issued $250 million of 2.90 percent 10-year debentures, $500 million of 4.30 percent 40-year debentures and

$550 million of 3.85 percent 30-year debentures, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes;

• Redeemed at maturity $400 million of 5.50 percent 10-year debentures; and

• Redeemed at maturity $250 million of 5.30 percent 10-year debentures.

2015

• Issued $650 million of 4.50 percent 30-year debentures, 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 $350 million of 5.375 percent 10-year debentures.

2014

• Issued $750 million of 4.625 percent 40-year debentures, $250 million of 3.30 percent 10-year debentures and $850 million of 4.45 percent 30-year debentures, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes;

• Redeemed at maturity $200 million of 4.70 percent 10-year debentures; and

• Redeemed at maturity $275 million of 5.55 percent 5-year debentures.

Con Edison's net cash flows from financing activities during the years ended December 31, 2016 and 2015 also reflect the following O&R transactions:

2016

• Issued $75 million of 3.88 percent 30-year debentures, the net proceeds from the sale of which were used to repay short-term borrowings; and

• Redeemed at maturity $75 million of 5.45 percent 10-year debentures.

2015

• Issued $100 million of 4.69 percent 30-year debentures and $120 million of 4.95 percent 30-year debentures, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes;

• Redeemed at maturity $40 million of 5.30 percent 10-year debentures;

• Redeemed at maturity $55 million of 2.50 percent 5-year debentures; and

• Redeemed at maturity $44 million of variable rate tax-exempt 20-year debt.

O&R had no long-term debt transactions in 2014.

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Con Edison's net cash flows from financing activities during the years ended December 31, 2016 and 2015 also reflect the following Clean Energy Businesses transactions:

2016

• Borrowed $2 million pursuant to a loan agreement with a New Jersey utility. The borrowing matures in 2026, bears interest of 11.18 percent and may be repaid in cash or project Solar Renewable Energy Certificates;

• Issued $95 million of 4.07 percent senior notes, due 2036, secured by the company's California Holdings 3 renewable electric production project; and

• Issued $218 million of 4.21 percent senior notes, due 2041, secured by the company's Texas Solar 7 renewable electric production project.

2015

• Issued $118 million of 3.94 percent senior notes, due in 2036, secured by the company's California Holdings 2 renewable electric production project; and

• Issued $159 million of 4.53 percent senior notes due in 2040, secured by the company's Texas Solar 5 renewable electric production project.

The Clean Energy Businesses had no issuances of long-term debt in 2014.

Cash flows from financing activities of the Companies also reflect commercial paper issuance. The commercial paper amounts outstanding at December 31, 2016, 2015 and 2014 and the average daily balances for 2016, 2015 and 2014 for Con Edison and CECONY were as follows:

	2016				2015				2014
(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	$1,054		$744		$1,529		$823		$801		$899
CECONY	$600		$362		$1,033		$379		$451		$765
Weighted average yield	1.0	%	0.6	%	0.7	%	0.4	%	0.4	%	0.2	%

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.

Other Changes in Assets and Liabilities

The following table shows changes in certain assets and liabilities at December 31, 2016, compared with December 31, 2015.

	Con Edison	CECONY
(Millions of Dollars)	2016 vs. 2015 Variance	2016 vs. 2015 Variance
Assets
Non-utility property, less accumulated depreciation	$650	$(1)
Investments	1,037	29
Regulatory asset – Unrecognized pension and other postretirement costs	(1,002)	(967)
Liabilities
Deferred income taxes and investment tax credits	$668	$695
System benefit charge	244	221
Pension and retiree benefits	(1,064)	(1,021)

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Non-Utility Property, Less Accumulated Depreciation

The increase in non-utility property, less accumulated depreciation, for Con Edison reflects the purchase of interests in, and construction expenditures for, renewable electric production projects. See "Clean Energy Businesses - Con Edison Development" and "Capital Requirements and Resources - Capital Requirements" in Item 1.

Investments

The increase in investments for Con Edison reflects primarily the purchase of a 50 percent equity interest in a gas pipeline and storage joint venture. See “Con Edison Transmission” in Item 1 and "Investments" in Note A and Note U to the financial statements in Item 8.

Regulatory Asset for Unrecognized Pension and Other Postretirement Costs and Liability for Pension and Retiree Benefits

The decrease in the regulatory asset for unrecognized pension and other postretirement costs and the liability for pension and retiree benefits reflects the final actuarial valuation of the pension and other retiree benefit plans as measured at December 31, 2016, in accordance with the accounting rules for retirement benefits. The change in the regulatory asset also reflects the year's amortization of accounting costs. The change in the liability for pension and retiree benefits reflects in part contributions to the plans made by the Utilities in 2016. See Notes B, E and F to the financial statements in Item 8.

Deferred Income Taxes and Investment Tax Credits

The increase in the liability for deferred income taxes and investment tax credits for Con Edison and CECONY reflects primarily bonus depreciation in 2016, partially offset by the increase in deferred income tax assets associated with the federal tax attribute carryforwards related to the net operating loss and general business tax credits. See Note L to the financial statements in Item 8.

System Benefit Charge

The increase in the liability for the system benefit charge reflects amounts collected by the Utilities from their customers that will be required to be paid to NYSERDA. See “Environmental Matters - Climate Change” in Item 1.

Off-Balance Sheet Arrangements

None of the Companies' interests in variable interest entities (VIEs) meet the SEC definition of off-balance sheet arrangements. For information regarding the Companies’ VIEs, see Note Q to the financial statements in Item 8.

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, goodwill and derivative instruments.

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.

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

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, 2016, the regulatory assets for Con Edison and CECONY were $7,124 million and $6,563 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 also provide such benefits to certain of their employees. 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 2016, 2015 and 2014.

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 2017 are decreases, compared with 2016, in their pension and other postretirement benefits costs of $85 million and $84 million, respectively.

The following table illustrates the effect on 2017 pension and other postretirement costs of changing the critical actuarial assumptions, while holding all other actuarial assumptions constant:

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Actuarial Assumption	Change in Assumption		Pension		Other Postretirement Benefits	Total
			(Millions of Dollars)
Increase in accounting cost:
Discount rate
Con Edison	(0.25	)%	$50		$3	$53
CECONY	(0.25	)%	$48		$2	$50
Expected return on plan assets
Con Edison	(0.25	)%	$31		$2	$33
CECONY	(0.25	)%	$29		$2	$31
Health care trend rate
Con Edison	1.00	%		$—	$1	$1
CECONY	1.00	%		$—	$(3)	$(3)
Increase in projected benefit obligation:
Discount rate
Con Edison	(0.25	)%	$512		$34	$546
CECONY	(0.25	)%	$482		$27	$509
Health care trend rate
Con Edison	1.00	%		$—	$(4)	$(4)
CECONY	1.00	%		$—	$(24)	$(24)

A 5.0 percentage point variation in the actual annual return in 2017, as compared with the expected annual asset return of 7.50 percent, would change pension and other postretirement benefit costs for Con Edison and CECONY by approximately $34 million and $32 million, respectively, in 2018.

Pension benefits are provided through a pension plan maintained by Con Edison to which CECONY, O&R and the Clean Energy Businesses 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 2016 under funding regulations and tax laws. However, CECONY and O&R made discretionary contributions to the pension plan in 2016 of $469 million and $39 million, respectively. In 2017, CECONY and O&R expect to make contributions to the pension plan of $388 million and $35 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 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.

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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 2015, Con Edison recorded a $5 million impairment charge on Pike assets held for sale. See Note U to the financial statements in Item 8. No impairment charges on long-lived assets were recognized in 2016 or 2014. No impairment charges on intangible assets with definite lives were recognized in 2016, 2015 or 2014. For information about the Companies' intangible assets, see Note K to the financial statements in Item 8.

Accounting for Goodwill

In accordance with the accounting rules for goodwill and intangible assets, Con Edison is required to test goodwill for impairment annually or whenever there is a triggering event. See Note K to the financial statements in Item 8. Goodwill is tested for impairment using a two-step quantitative approach. The first step of the goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, the second step is performed to measure the amount of impairment loss, if any. The second step requires a calculation of the implied fair value of goodwill.

Goodwill was $428 million at December 31, 2016, which consists of $406 million related to the O&R merger, $14 million related to a residential solar company owned by Con Edison Solutions and $8 million related to a gas storage company owned by Con Edison Development. The most recent tests, which were performed during 2016, required a second-step assessment to be performed on goodwill of $15 million related to two energy service companies owned by Con Edison Solutions. Based on the results of step two of the impairment test, Con Edison Solutions recorded an impairment charge of $15 million ($12 million, net of tax). A second-step assessment of the goodwill related to the O&R merger, residential solar company and gas storage company was not required. Con Edison's most significant assumptions for the goodwill impairment tests relate to the estimates of reporting unit fair values. The company estimated fair values using primarily discounted cash flows and market valuations for a proxy group of companies. Estimates of future cash flows, projected growth rates and discount rates inherent in the cash flow estimates for the gas storage and residential solar companies may vary significantly from actual results, which could result in a future impairment of goodwill.

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 O 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.

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, credit risk and investment risk.

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Interest Rate Risk

The Companies' interest rate risk relates primarily to variable rate debt and to new debt financing needed to fund capital requirements, including the construction expenditures of the Utilities and maturing debt securities. Con Edison and its businesses manage interest rate risk through the issuance of mostly fixed-rate debt with varying maturities and through opportunistic refinancing of debt. Con Edison and CECONY estimate that at December 31, 2016, a 10 percent increase in interest rates applicable to its variable rate debt would result in an increase in annual interest expense of $3 million. Under CECONY’s current electric, gas and steam rate plans, variations in actual variable rate tax-exempt debt interest expense are reconciled to levels reflected in rates.

Commodity Price Risk

Con Edison’s commodity price risk relates primarily 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 O to the financial statements in Item 8.

Con Edison estimates that, as of December 31, 2016, a 10 percent decline in market prices would result in a decline in fair value of $68 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $60 million is for CECONY and $8 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 and 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, 2016 and 2015, respectively, was as follows:

95% Confidence Level, One-Day Holding Period	2016	2015
	(Millions of Dollars)
Average for the period	$2	$1
High	4	2
Low	1	—

Credit Risk

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. See “Credit Exposure” in Note O to the financial statements in Item 8.

Investment Risk

The Companies’ investment risk relates to the investment of plan assets for their pension and other postretirement benefit plans and to the investments of the Clean Energy Businesses and 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 Notes A, E and F to the financial statements in Item 8.

The Companies’ current investment policy for pension plan assets includes investment targets of 52 to 64 percent equities and 35 to 49 percent fixed income and other securities. At December 31, 2016, the pension plan investments consisted of 58 percent equity and 42 percent fixed income and other securities.

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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.

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).

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).

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Item 8:    Financial Statements and Supplementary Data

Financial Statements	Page
Supplementary Financial Information
Con Edison
Report of Management on Internal Control Over Financial Reporting	77
Report of Independent Registered Public Accounting Firm	78
Consolidated Income Statement for the years ended December 31, 2016, 2015 and 2014	79
Consolidated Statement of Comprehensive Income for the years ended December 31, 2016, 2015 and 2014	80
Consolidated Statement of Cash Flows for the years ended December 31, 2016, 2015 and 2014	81
Consolidated Balance Sheet at December 31, 2016 and 2015	82
Consolidated Statement of Equity for the years ended December 31, 2016, 2015 and 2014	84
Consolidated Statement of Capitalization at December 31, 2016 and 2015	85
CECONY
Report of Management on Internal Control Over Financial Reporting	88
Report of Independent Registered Public Accounting Firm	89
Consolidated Income Statement for the years ended December 31, 2016, 2015 and 2014	90
Consolidated Statement of Comprehensive Income for the years ended December 31, 2016, 2015 and 2014	91
Consolidated Statement of Cash Flows for the years ended December 31, 2016, 2015 and 2014	92
Consolidated Balance Sheet at December 31, 2016 and 2015	93
Consolidated Statement of Shareholder’s Equity for the years ended December 31, 2016, 2015 and 2014	95
Consolidated Statement of Capitalization at December 31, 2016 and 2015	96
Notes to the Financial Statements	98
Financial Statement Schedules
Con Edison
Schedule I – Condensed Financial Information	152
Schedule II – Valuation and Qualifying Accounts	155
CECONY
Schedule II – Valuation and Qualifying Accounts	155

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

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Supplementary Financial Information

Selected Quarterly Financial Data for the years ended December 31, 2016 and 2015 (Unaudited)

	2016
Con Edison	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	(Millions of Dollars, except per share amounts)
Operating revenues	$3,156	$2,794	$3,417	$2,707
Operating income	642	515	940	478
Net income	310	232	497	207
Basic earnings per share	$1.05	$0.78	$1.63	$0.68
Diluted earnings per share	$1.05	$0.77	$1.62	$0.67

	2015
Con Edison	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	(Millions of Dollars, except per share amounts)
Operating revenues	$3,616	$2,788	$3,443	$2,707
Operating income	726	472	830	399
Net income	370	219	428	176
Basic earnings per share	$1.26	$0.75	$1.46	$0.60
Diluted earnings per share	$1.26	$0.74	$1.45	$0.60

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.

	2016
CECONY	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	(Millions of Dollars)
Operating revenues	$2,632	$2,281	$2,828	$2,424
Operating income	640	392	766	463
Net income	310	161	388	197

	2015
CECONY	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	(Millions of Dollars)
Operating revenues	$3,010	$2,283	$2,829	$2,206
Operating income	684	460	745	358
Net income	348	211	375	149

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.

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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, 2016, 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, 2016.

The effectiveness of the Company’s internal control over financial reporting as of December 31, 2016, 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/ John McAvoy

John McAvoy

Chairman, President and Chief Executive Officer

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

February 16, 2017

77

Report of Independent Registered Public Accounting Firm

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

In our opinion, the consolidated financial statements listed in the accompanying index present fairly, in all material respects, the financial position of Consolidated Edison, Inc. and its subsidiaries (the Company) at December 31, 2016 and 2015, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2016 in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedules listed in the accompanying index present fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2016, based on criteria established in Internal Control—Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company’s management is responsible for these financial statements and financial statement schedules, 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 these financial statements, on the financial statement schedules, and on the Company’s internal control over financial reporting based on our integrated audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. 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.

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 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.

/s/ PricewaterhouseCoopers LLP

New York, New York

February 16, 2017

78

Consolidated Edison, Inc.

Consolidated Income Statement

	For the Years Ended December 31,
(Millions of Dollars/Except Share Data)	2016	2015	2014
OPERATING REVENUES
Electric	$8,741	$8,832	$9,114
Gas	1,692	1,709	1,933
Steam	551	629	628
Non-utility	1,091	1,384	1,244
TOTAL OPERATING REVENUES	12,075	12,554	12,919
OPERATING EXPENSES
Purchased power	2,439	2,973	3,417
Fuel	172	248	285
Gas purchased for resale	477	495	811
Other operations and maintenance	3,269	3,344	3,294
Depreciation and amortization	1,216	1,130	1,071
Taxes, other than income taxes	2,031	1,937	1,877
TOTAL OPERATING EXPENSES	9,604	10,127	10,755
Gain on sale of retail electric supply business and solar electric production projects	104	—	45
OPERATING INCOME	2,575	2,427	2,209
OTHER INCOME (DEDUCTIONS)
Investment and other income	91	35	54
Allowance for equity funds used during construction	10	5	2
Other deductions	(37)	(16)	(14)
TOTAL OTHER INCOME	64	24	42
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,639	2,451	2,251
INTEREST EXPENSE
Interest on long-term debt	678	632	587
Other interest	24	24	5
Allowance for borrowed funds used during construction	(6)	(3)	(1)
NET INTEREST EXPENSE	696	653	591
INCOME BEFORE INCOME TAX EXPENSE	1,943	1,798	1,660
INCOME TAX EXPENSE	698	605	568
NET INCOME	$1,245	$1,193	$1,092
Net income per common share — basic	$4.15	$4.07	$3.73
Net income per common share — diluted	$4.12	$4.05	$3.71
DIVIDENDS DECLARED PER COMMON SHARE	$2.68	$2.60	$2.52
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (IN MILLIONS)	300.4	293.0	292.9
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (IN MILLIONS)	301.9	294.4	294.0

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

79

Consolidated Edison, Inc.

Consolidated Statement of Comprehensive Income

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
NET INCOME	$1,245	$1,193	$1,092
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	7	11	(20)
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	7	11	(20)
COMPREHENSIVE INCOME	$1,252	$1,204	$1,072

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

80

Consolidated Edison, Inc.

Consolidated Statement of Cash Flows

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015		2014
OPERATING ACTIVITIES
Net Income	$1,245	$1,193		$1,092
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,216	1,130		1,071
Deferred income taxes	783	653		518
Rate case amortization and accruals	(210)	(52)		121
Common equity component of allowance for funds used during construction	(10)	(5)		(2)
Net derivative (gains)/losses	(6)	3		128
Pre-tax gain on sale of retail electric supply business and solar electric production projects	(104)	—		(45)
Other non-cash items, net	142	77		(35)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(69)	96		44
Materials and supplies, including fuel oil and gas in storage	13	22		(10)
Other receivables and other current assets	54	(27)		316
Income taxes receivable	87	58		(224)
Prepayments	20	(14)		(27)
Accounts payable	29	(79)		(9)
Pensions and retiree benefits obligations, net	609	756		822
Pensions and retiree benefits contributions	(515)	(756)		(584)
Accrued taxes	2	(10)		(404)
Accrued interest	14	4		(113)
Superfund and environmental remediation costs, net	69	22		28
Distributions from equity investments	68	31		—
System benefit charge	244	38		(37)
Deferred charges, noncurrent assets and other regulatory assets	(97)	(111)		(361)
Deferred credits and other regulatory liabilities	(68)	182		498
Other current and noncurrent liabilities	(57)	66		44
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,459	3,277		2,831
INVESTING ACTIVITIES
Utility construction expenditures	(2,835)	(2,562)		(2,239)
Cost of removal less salvage	(206)	(219)		(216)
Non-utility construction expenditures	(845)	(492)		(180)
Investments in electric and gas transmission projects	(1,076)	—		—
Investments in/acquisitions of renewable electric production projects	(402)	(299)		(293)
Proceeds from grants related to solar electric production projects	—	—		36
Proceeds from sale of assets	252	—		108
Restricted cash	(17)	(13)		15
Proceeds from the transfer of assets to NY Transco	122	—		—
Other investing activities	31	(72)		10
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,976)	(3,657)		(2,759)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(475)	729		(651)
Issuance of long-term debt	2,590	1,147		1,850
Retirement of long-term debt	(735)	(500)		(480)
Debt issuance costs	(24)	(15)		(17)
Common stock dividends	(763)	(733)		(739)
Issuance of common shares - public offering	702	—		—
Issuance of common shares for stock plans, net of repurchases	51	1		(10)
Distribution to noncontrolling interest	(1)	—		—
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	1,345	629		(47)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(172)	249		25
BALANCE AT BEGINNING OF PERIOD	944	699		674
BALANCE AT END OF PERIOD	772	948		699
LESS: CHANGE IN CASH BALANCES HELD FOR SALE	(4)	4		—
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	$776	$944		$699
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$664	$597		$561
Income taxes	$(180)	$(36)		$633
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$388	$279		$179
Issuance of common shares for dividend reinvestment	$46	$28		$11
Debt assumed with business acquisitions	$195		$—		$—

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

81

Consolidated Edison, Inc.

Consolidated Balance Sheet

(Millions of Dollars)	December 31, 2016	December 31, 2015
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$776	$944
Accounts receivable — customers, less allowance for uncollectible accounts of $69 and $85 in 2016 and 2015, respectively	1,106	1,052
Other receivables, less allowance for uncollectible accounts of $14 and $11 in 2016 and 2015, respectively	195	304
Income taxes receivable	79	166
Accrued unbilled revenue	447	360
Fuel oil, gas in storage, materials and supplies, at average cost	339	350
Prepayments	159	177
Regulatory assets	100	132
Assets held for sale	—	157
Other current assets	205	194
TOTAL CURRENT ASSETS	3,406	3,836
INVESTMENTS	1,921	884
UTILITY PLANT, AT ORIGINAL COST
Electric	27,747	26,358
Gas	7,524	6,858
Steam	2,421	2,336
General	2,719	2,622
TOTAL	40,411	38,174
Less: Accumulated depreciation	8,541	8,044
Net	31,870	30,130
Construction work in progress	1,175	1,003
NET UTILITY PLANT	33,045	31,133
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $140 and $95 in 2016 and 2015, respectively	1,482	832
Construction work in progress	689	244
NET PLANT	35,216	32,209
OTHER NONCURRENT ASSETS
Goodwill	428	429
Intangible assets, less accumulated amortization of $6 and $4 in 2016 and 2015, respectively	124	2
Regulatory assets	7,024	8,096
Other deferred charges and noncurrent assets	136	186
TOTAL OTHER NONCURRENT ASSETS	7,712	8,713
TOTAL ASSETS	$48,255	$45,642

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

82

Consolidated Edison, Inc.

Consolidated Balance Sheet

(Millions of Dollars)	December 31, 2016	December 31, 2015
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$39	$739
Notes payable	1,054	1,529
Accounts payable	1,147	1,008
Customer deposits	352	354
Accrued taxes	64	62
Accrued interest	150	136
Accrued wages	101	97
Fair value of derivative liabilities	77	66
Regulatory liabilities	128	115
Liabilities held for sale	—	89
System benefit charge	434	190
Other current liabilities	297	335
TOTAL CURRENT LIABILITIES	3,843	4,720
NONCURRENT LIABILITIES
Provision for injuries and damages	160	185
Pensions and retiree benefits	1,847	2,911
Superfund and other environmental costs	753	765
Asset retirement obligations	246	242
Fair value of derivative liabilities	40	39
Deferred income taxes and unamortized investment tax credits	10,205	9,537
Regulatory liabilities	1,905	1,977
Other deferred credits and noncurrent liabilities	215	199
TOTAL NONCURRENT LIABILITIES	15,371	15,855
LONG-TERM DEBT	14,735	12,006
EQUITY
Common shareholders’ equity	14,298	13,052
Noncontrolling interest	8	9
TOTAL EQUITY (See Statement of Equity)	14,306	13,061
TOTAL LIABILITIES AND EQUITY	$48,255	$45,642

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

83

Consolidated Edison, Inc.

Consolidated Statement of Equity

(In Millions)	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, 2013	293	$32	$4,995	$8,338	23	$(1,034)	$(61)	$(25)		$—	$12,245
Net income				1,092							1,092
Common stock dividends				(739)							(739)
Issuance of common shares for stock plans, net of repurchases	—		(4)		—	2					(2)
Other comprehensive loss								(20)			(20)
Noncontrolling interest									9		9
BALANCE AS OF DECEMBER 31, 2014	293	$32	$4,991	$8,691	23	$(1,032)	$(61)	$(45)	$9		$12,585
Net income				1,193							1,193
Common stock dividends				(761)							(761)
Issuance of common shares for stock plans, net of repurchases	—		39		—	(6)					33
Other comprehensive income								11			11
Noncontrolling interest									—		—
BALANCE AS OF DECEMBER 31, 2015	293	$32	$5,030	$9,123	23	$(1,038)	$(61)	$(34)	$9		$13,061
Net income				1,245							1,245
Common stock dividends				(809)							(809)
Issuance of common shares - public offering	10	1	723				(22)				702
Issuance of common shares for stock plans	2		101								101
Other comprehensive income								7			7
Noncontrolling interest									(1)		(1)
BALANCE AS OF DECEMBER 31, 2016	305	$33	$5,854	$9,559	23	$(1,038)	$(83)	$(27)	$8		$14,306

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

84

Consolidated Edison, Inc.

Consolidated Statement of Capitalization

	Shares outstanding December 31,		At December 31,
(In Millions)	2016	2015	2016	2015
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS	305	293	$14,325	$13,086
Pension plan liability adjustments, net of taxes			(24)	(31)
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			(3)	(3)
TOTAL ACCUMULATED OTHER COMPREHENSIVE LOSS, NET OF TAXES			(27)	(34)
Equity			14,298	13,052
Noncontrolling interest			8	9
TOTAL EQUITY (See Statement of Equity)			$14,306	$13,061

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

85

Consolidated Edison, Inc.

Consolidated Statement of Capitalization

LONG-TERM DEBT (Millions of Dollars)			At December 31,
Maturity	Interest Rate	Series	2016		2015
DEBENTURES:
2016	5.45%	2006A		$—	$75
2016	5.50	2006C	—		400
2016	5.30	2006D	—		250
2018	5.85	2008A	600		600
2018	6.15	2008A	50		50
2018	7.125	2008C	600		600
2019	4.96	2009A	60		60
2019	6.65	2009B	475		475
2020	4.45	2010A	350		350
2021	2.00	2016A	500		—
2024	3.30	2014B	250		250
2026	2.90	2016B	250		—
2027	6.50	1997F	80		80
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
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		—
2046	3.88	2016A	75		—
2054	4.625	2014C	750		750
2056	4.30	2016C	500		—
TOTAL DEBENTURES			12,260		11,110

86

Consolidated Edison, Inc.

Consolidated Statement of Capitalization

LONG-TERM DEBT (Millions of Dollars)			At December 31,
Maturity	Interest Rate	Series	2016	2015
TAX-EXEMPT DEBT - Notes issued to New York State Energy Research and Development Authority for Facilities Revenue Bonds (a):
2032	0.98%	2004B Series 1	$127	$127
2034	0.98	1999A	293	293
2035	0.998	2004B Series 2	20	20
2036	1.134	2001B	98	98
2036	0.745	2010A	225	225
2039	0.963	2004A	98	98
2039	0.74	2004C	99	99
2039	0.723	2005A	126	126
TOTAL TAX-EXEMPT DEBT			1,086	1,086
PROJECT DEBT:
2024-2032	Variable - 4.52%	Coram	180	—
2031-2038	5.25 - 4.95	Texas Solar 4	64	64
2036	3.94	California Solar 2	114	115
2036	4.07	California Solar 3	95	—
2040	4.53	Texas Solar 5	158	159
2041	4.21	Texas Solar 7	218	—
Other project debt			16	1
TOTAL PROJECT DEBT			845	339
Long-term debt - Variable rate term loan			400	—
Other long-term debt			317	323
Unamortized debt expense			(107)	(91)
Unamortized debt discount			(27)	(22)
TOTAL			14,774	12,745
Less: Long-term debt due within one year			39	739
TOTAL LONG-TERM DEBT			14,735	12,006
TOTAL CAPITALIZATION			$29,033	$25,058

(a) Rates are to be reset weekly or by auction held every 35 days; December 31, 2016 rates shown.

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

87

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, 2016, 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, 2016.

The effectiveness of the Company’s internal control over financial reporting as of December 31, 2016, 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/ John McAvoy

John McAvoy

Chairman and Chief Executive Officer

/s/ Robert Hoglund

Robert Hoglund

Senior Vice President and Chief Financial Officer

February 16, 2017

88

Report of Independent Registered Public Accounting Firm

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

In our opinion, the consolidated financial statements listed in the accompanying index present fairly, in all material respects, the financial position of Consolidated Edison Company of New York, Inc. and its subsidiaries (the Company) at December 31, 2016 and 2015, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2016 in conformity with accounting principles generally accepted in the United States of America. In addition, in our opinion, the financial statement schedule listed in the accompanying index presents fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidated financial statements. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2016, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company’s management is responsible for these financial statements and financial statement schedule, 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 these financial statements, on the financial statement schedule, and on the Company’s internal control over financial reporting based on our integrated audits. We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. 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.

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 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.

/s/ PricewaterhouseCoopers LLP

New York, New York

February 16, 2017

89

Consolidated Edison Company of New York, Inc.

Consolidated Income Statement

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
OPERATING REVENUES
Electric	$8,106	$8,172	$8,437
Gas	1,508	1,527	1,721
Steam	551	629	628
TOTAL OPERATING REVENUES	10,165	10,328	10,786
OPERATING EXPENSES
Purchased power	1,568	1,719	2,091
Fuel	172	248	285
Gas purchased for resale	319	337	609
Other operations and maintenance	2,806	2,881	2,873
Depreciation and amortization	1,106	1,040	991
Taxes, other than income taxes	1,932	1,856	1,798
TOTAL OPERATING EXPENSES	7,903	8,081	8,647
OPERATING INCOME	2,262	2,247	2,139
OTHER INCOME (DEDUCTIONS)
Investment and other income	8	5	22
Allowance for equity funds used during construction	8	4	1
Other deductions	(16)	(14)	(12)
TOTAL OTHER INCOME (DEDUCTIONS)	—	(5)	11
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,262	2,242	2,150
INTEREST EXPENSE
Interest on long-term debt	588	567	523
Other interest	19	19	15
Allowance for borrowed funds used during construction	(4)	(2)	(1)
NET INTEREST EXPENSE	603	584	537
INCOME BEFORE INCOME TAX EXPENSE	1,659	1,658	1,613
INCOME TAX EXPENSE	603	574	555
NET INCOME	$1,056	$1,084	$1,058

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

90

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Comprehensive Income

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
NET INCOME	$1,056	$1,084	$1,058
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	2	2	(5)
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	2	2	(5)
COMPREHENSIVE INCOME	$1,058	$1,086	$1,053

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

91

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Cash Flows

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
OPERATING ACTIVITIES
Net income	$1,056	$1,084	$1,058
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,106	1,040	991
Deferred income taxes	545	449	331
Rate case amortization and accruals	(227)	(74)	102
Common equity component of allowance for funds used during construction	(8)	(4)	(1)
Other non-cash items, net	(31)	(27)	(33)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(23)	87	59
Materials and supplies, including fuel oil and gas in storage	18	24	(12)
Other receivables and other current assets	(11)	38	48
Accounts receivables from affiliated companies	81	(58)	(13)
Prepayments	13	13	(24)
Accounts payable	20	(51)	(57)
Accounts payable to affiliated companies	(2)	(11)	(22)
Pensions and retiree benefits obligations, net	579	714	742
Pensions and retiree benefits contributions	(476)	(703)	(544)
Superfund and environmental remediation costs, net	79	19	32
Accrued taxes	1	3	—
Accrued taxes to affiliated companies	117	(8)	(403)
Accrued interest	(7)	1	(22)
System benefit charge	221	38	(38)
Deferred charges, noncurrent assets and other regulatory assets	(172)	(150)	(334)
Deferred credits and other regulatory liabilities	179	379	475
Other current and noncurrent liabilities	(20)	16	95
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,038	2,819	2,430
INVESTING ACTIVITIES
Utility construction expenditures	(2,672)	(2,410)	(2,094)
Cost of removal less salvage	(203)	(212)	(210)
Proceeds from the transfer of assets to NY Transco	122	—	—
Restricted cash	14	(16)	—
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,739)	(2,638)	(2,304)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(433)	583	(760)
Issuance of long-term debt	1,300	650	1,850
Retirement of long-term debt	(650)	(350)	(475)
Debt issuance costs	(13)	(7)	(17)
Capital contribution by parent	100	13	—
Dividend to parent	(744)	(872)	(712)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	(440)	17	(114)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(141)	198	12
BALANCE AT BEGINNING OF PERIOD	843	645	633
BALANCE AT END OF PERIOD	$702	$843	$645
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$581	$554	$504
Income taxes	$(162)	$163	$748
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$295	$210	$151

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

92

Consolidated Edison Company of New York, Inc.

Consolidated Balance Sheet

(Millions of Dollars)	December 31, 2016	December 31, 2015
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$702	$843
Accounts receivable – customers, less allowance for uncollectible accounts of $65 and $80 in 2016 and 2015, respectively	1,032	987
Other receivables, less allowance for uncollectible accounts of $13 and $11 in 2016 and 2015, respectively	81	70
Accrued unbilled revenue	399	327
Accounts receivable from affiliated companies	109	190
Fuel oil, gas in storage, materials and supplies, at average cost	270	288
Prepayments	100	113
Regulatory assets	90	121
Other current assets	97	133
TOTAL CURRENT ASSETS	2,880	3,072
INVESTMENTS	315	286
UTILITY PLANT AT ORIGINAL COST
Electric	26,122	24,828
Gas	6,814	6,191
Steam	2,421	2,336
General	2,490	2,411
TOTAL	37,847	35,766
Less: Accumulated depreciation	7,836	7,378
Net	30,011	28,388
Construction work in progress	1,104	922
NET UTILITY PLANT	31,115	29,310
NON-UTILITY PROPERTY
Non-utility property, less accumulated depreciation of $25 in 2016 and 2015	4	5
NET PLANT	31,119	29,315
OTHER NONCURRENT ASSETS
Regulatory assets	6,473	7,482
Other deferred charges and noncurrent assets	69	75
TOTAL OTHER NONCURRENT ASSETS	6,542	7,557
TOTAL ASSETS	$40,856	$40,230

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

93

Consolidated Edison Company of New York, Inc.

Consolidated Balance Sheet

(Millions of Dollars)	December 31, 2016		December 31, 2015
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year		$—	$650
Notes payable	600		1,033
Accounts payable	876		771
Accounts payable to affiliated companies	10		12
Customer deposits	336		339
Accrued taxes	50		49
Accrued taxes to affiliated companies	119		2
Accrued interest	111		118
Accrued wages	91		88
Fair value of derivative liabilities	66		50
Regulatory liabilities	90		84
System benefit charge	398		177
Other current liabilities	242		266
TOTAL CURRENT LIABILITIES	2,989		3,639
NONCURRENT LIABILITIES
Provision for injuries and damages	154		178
Pensions and retiree benefits	1,544		2,565
Superfund and other environmental costs	655		665
Asset retirement obligations	227		234
Fair value of derivative liabilities	33		36
Deferred income taxes and unamortized investment tax credits	9,450		8,755
Regulatory liabilities	1,712		1,789
Other deferred credits and noncurrent liabilities	190		167
TOTAL NONCURRENT LIABILITIES	13,965		14,389
LONG-TERM DEBT	12,073		10,787
COMMON SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	11,829		11,415
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$40,856		$40,230

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

94

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, 2013	235	$589	$4,234	$7,053	$(962)	$(61)	$(6)	$10,847
Net income				1,058				1,058
Common stock dividend to parent				(712)				(712)
Other comprehensive loss							(5)	(5)
BALANCE AS OF DECEMBER 31, 2014	235	$589	$4,234	$7,399	$(962)	$(61)	$(11)	$11,188
Net income				1,084				1,084
Common stock dividend to parent				(872)				(872)
Capital contribution by parent			13					13
Other comprehensive income							2	2
BALANCE AS OF DECEMBER 31, 2015	235	$589	$4,247	$7,611	$(962)	$(61)	$(9)	$11,415
Net income				1,056				1,056
Common stock dividend to parent				(744)				(744)
Capital contribution by parent			100					100
Other comprehensive income							2	2
BALANCE AS OF DECEMBER 31, 2016	235	$589	$4,347	$7,923	$(962)	$(61)	$(7)	$11,829

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

95

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Capitalization

	Shares outstanding
	December 31,	December 31,	At December 31,
(In Millions)	2016	2015	2016	2015
TOTAL SHAREHOLDER’S EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS	235	235	$11,836	$11,424
Pension plan liability adjustments, net of taxes			(4)	(6)
Unrealized gains on derivatives qualified as cash flow hedges, less reclassification adjustment for gains included in net income, net of taxes			(3)	(3)
TOTAL ACCUMULATED OTHER COMPREHENSIVE LOSS, NET OF TAXES			(7)	(9)
TOTAL SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)			$11,829	$11,415

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

96

Consolidated Edison Company of New York, Inc.

Consolidated Statement of Capitalization

LONG-TERM DEBT (Millions of Dollars)			At December 31,
Maturity	Interest Rate	Series	2016		2015
DEBENTURES:
2016	5.50%	2006C		$—	$400
2016	5.30	2006D	—		250
2018	5.85	2008A	600		600
2018	7.125	2008C	600		600
2019	6.65	2009B	475		475
2020	4.45	2010A	350		350
2024	3.30	2014B	250		250
2026	2.90	2016B	250		—
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		—
2054	4.625	2014C	750		750
2056	4.30	2016C	500		—
TOTAL DEBENTURES			11,100		10,450
TAX-EXEMPT DEBT – Notes issued to New York State Energy Research and Development Authority for Facilities Revenue Bonds*:
2032	0.98%	2004B Series 1	127		127
2034	0.98	1999A	293		293
2035	0.998	2004B Series 2	20		20
2036	1.134	2001B	98		98
2036	0.745	2010A	225		225
2039	0.963	2004A	98		98
2039	0.74	2004C	99		99
2039	0.723	2005A	126		126
TOTAL TAX-EXEMPT DEBT			1,086		1,086
Unamortized debt expense			(87)		(78)
Unamortized debt discount			(26)		(21)
TOTAL			12,073		11,437
Less: Long-term debt due within one year			—		650
TOTAL LONG-TERM DEBT			12,073		10,787
TOTAL CAPITALIZATION			$23,902		$22,202

* Rates are to be reset weekly or by auction held every 35 days; December 31, 2016 rates shown.

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

97

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. The Clean Energy Businesses, Inc. has three subsidiaries: Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company that provides energy-related products and services to retail customers. Con Edison Transmission, Inc. invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See Note U.

Note A – Summary of Significant Accounting Policies

Principles of Consolidation

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

Accounting Policies

The accounting policies of Con Edison and its subsidiaries conform to 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. The Utilities are receiving or being credited with a return on all of their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on all of their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable state regulators.

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

98

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 R.

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 4.7 percent, 4.4 percent and 1.6 percent for 2016, 2015 and 2014, respectively. The AFUDC rates for O&R were 3.5 percent, 0.4 percent and 2.6 percent for 2016, 2015 and 2014, 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 3.1 percent for 2016, 2015 and 2014. The average depreciation rates for O&R were 2.9 percent, 3.0 percent and 2.9 percent for 2016, 2015 and 2014, respectively.

The estimated lives for utility plant for CECONY range from 5 to 85 years for electric and 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, 2016 and 2015, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Electric
Generation	$479	$459	$479	$459
Transmission	3,184	3,045	2,963	2,833
Distribution	18,150	17,244	17,234	16,394
Gas (a)	6,285	5,698	5,749	5,196
Steam	1,882	1,849	1,882	1,849
General	1,816	1,758	1,639	1,592
Held for future use	74	77	65	65
Construction work in progress	1,175	1,003	1,104	922
Net Utility Plant	$33,045	$31,133	$31,115	$29,310

(a) Primarily distribution.

Under the Utilities’ rate plans, the aggregate annual depreciation allowance in effect at December 31, 2016 was $1,176 million, including $1,106 million under CECONY’s electric, gas and steam rate plans that have been approved by the New York State Public Service Commission (NYSPSC).

Non-Utility Plant

Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the Clean Energy Businesses’ renewable electric production and gas storage. 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 range from 3 to 30 years.

99

Goodwill

Con Edison tests 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 two-step, quantitative goodwill impairment test. However, Con Edison has not elected to perform the qualitative assessment and exclusively applies the two-step quantitative approach. The first step of the goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, the second step is performed to measure the amount of impairment loss, if any. The second step requires a calculation of the implied fair value of goodwill. In 2016, Con Edison Solutions recorded a $15 million impairment charge on goodwill. See Note K.

Long-Lived and Intangible Assets

Con Edison evaluates the impairment of long-lived assets and intangible assets with definite lives, based on projections of undiscounted future cash flows, whenever events or changes in circumstances indicate that the carrying amounts of such assets may not be recoverable. In the event an evaluation indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are written down to their estimated fair value. In 2015, Con Edison recorded a $5 million impairment charge on the assets held for sale of Pike County Light & Power Company (Pike), a former O&R subsidiary that was sold in August 2016 (see Note U). No impairment charges on long-lived assets were recognized in 2016 or 2014. No impairment charges on intangible assets with definite lives were recognized in 2016, 2015, or 2014. For information about the Companies' intangible assets, see Note K.

Revenues

The Utilities recognize and, until the sale of its retail electric supply business in September 2016 (see Note U), Con Edison Solutions recognized revenues for energy service on a monthly billing cycle basis. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers. The Utilities accrue and Con Edison Solutions accrued revenues at the end of each month for estimated energy service not yet billed to customers.

CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism under which the company’s actual energy delivery revenues are compared 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)	2016	2015	2014
Con Edison	$336	$354	$365
CECONY	316	331	343

For information about changes to the accounting rules for revenue recognition, see Note T.

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.

100

New York Independent System Operator (NYISO)

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

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

Temporary Cash Investments

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

Investments

Investments consist primarily of the investments of Con Edison Transmission and the Clean Energy Businesses 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 following investment assets are included in the Companies' consolidated balance sheets at December 31, 2016 and 2015:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015		2016		2015
CET Gas investment in Stagecoach Gas Services, LLC (a)	$992		$—		$—		$—
Con Edison Development equity method investments (b)	488	574		—		—
Supplemental retirement income plan assets (c)	273	243		246		221
Deferred income plan assets	60	55		60		55
CET Electric investment in New York Transco, LLC	51	3		—		—
CET Gas investment in Mountain Valley Pipeline, LLC	48	—		—		—
Other	9	9		9		10
Total investments	$1,921	$884		$315		$286

(a) See Note U.

(b) See Note Q.

(c) 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.

101

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. Generally, O&R also defers such difference pursuant to its 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 tax liability, the Utilities have established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense. See Notes B and L. In 1993, the NYSPSC issued a Policy Statement approving accounting procedures consistent with accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. See Note L.

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

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)	2016	2015	2014
Con Edison	$24	$23	$22
CECONY	22	22	20

Reclassification

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

102

Earnings Per Common Share

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

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

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

	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2014
Net income	$1,245	$1,193	$1,092
Weighted average common shares outstanding – basic	300.4	293.0	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.5	1.4	1.1
Adjusted weighted average common shares outstanding – diluted	301.9	294.4	294.0
Net Income per common share – basic	$4.15	$4.07	$3.73
Net Income per common share – diluted	$4.12	$4.05	$3.71

The computation of diluted EPS for the year ended December 31, 2014 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, 2014 (a)	$(45)	$(11)
OCI before reclassifications, net of tax of $(3) for Con Edison	5	1
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(4) and $(1) for Con Edison and CECONY, respectively(a)(b)	6	1
Total OCI, net of taxes, at December 31, 2015	11	2
Accumulated OCI, net of taxes, at December 31, 2015 (a)	$(34)	$(9)
OCI before reclassifications, net of tax of $(1) for Con Edison and CECONY	2	1
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(3) and $(1) for Con Edison and CECONY, respectively(a)(b)	5	1
Total OCI, net of taxes, at December 31, 2016	7	2
Accumulated OCI, net of taxes, at December 31, 2016 (a)	$(27)	$(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 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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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 New Jersey Board of Public Utilities (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. 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.

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.

Rate base is, in general, the sum of the Utilities’ net plant and working capital less deferred taxes. 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 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:

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CECONY – Electric
Effective period	January 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(76.2) million (a) Yr. 2 – $124.0 million (a) Yr. 3 – None	Yr. 1 - $195 million (b) Yr. 2 - $155 million (b) Yr. 3 - $155 million (b)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 and 2 – $(37) million (c) Yr. 3 - $123 million (c)	Yr. 1 - $84 million Yr. 2 - $83 million Yr. 3 - $69 million
Other revenue sources	Retention of $90 million of annual transmission congestion revenues.	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
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred for customer benefit $146 million, $98 million and $101 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs (d)	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties (up to $400 million annually) if certain performance targets are not met. In 2014, the company recorded a $5 million negative revenue adjustment. In 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $376 million Yr. 2 - $383 million Yr. 3 - $395 million.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $57 million, $26 million and $68 million of net regulatory liabilities, respectively (e).	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)
Net utility plant reconciliations	Target levels reflected in rates were: Transmission and distribution: Yr. 1 – $16,869 million Yr. 2 – $17,401 million Yr. 3 – $17,929 million Storm hardening: Yr. 1 – $89 million; Yr. 2 – $177 million; Yr. 3 – $268 million Other: Yr. 1 – $2,034 million; Yr. 2 – $2,102 million; Yr. 3 – $2,069 million The company deferred $6 million and $17 million as a regulatory liability in 2014 and 2015, respectively. In 2016, $9 million was deferred as a regulatory asset.	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
Average rate base	Yr. 1 – $17,323 million Yr. 2 – $18,113 million Yr. 3 – $18,282 million	Yr. 1 - $18,902 million Yr. 2 - $19,530 million Yr. 3 - $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.05 percent Yr. 2 – 7.08 percent Yr. 3 – 6.91 percent	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	Yrs. 1 and 2 – 9.2 percent Yr. 3 – 9.0 percent	9.0 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.8 percent for Yrs. 1 and 2 and 9.6 percent for Yr. 3 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 $44.4 million and $6.5 million above the threshold for 2015 and 2016, respectively.	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.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.09 percent	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $30 million regulatory liability at December 31, 2015; this amount has been amortized to $0 at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's electric rate plan for January 2017 through December 2019. The electric base rate increases are in addition to a $48 million increase resulting from the December 2016 expiration of a

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temporary credit under the prior rate plan. At the NYSPSC’s option, these increases are being 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 ten-year period, including the overall pre-tax rate of return on such costs.

(c) Amounts reflect annual amortization of $107 million of the regulatory asset for deferred Superstorm Sandy and other major storm costs. The costs recoverable from customers were reduced by $4 million. The costs are no longer subject to NYSPSC staff review and the recovery of the costs is no longer subject to refund. In 2016, an additional $123 million of net regulatory liabilities were amortized to income.

(d) For transmission service provided pursuant to the open access transmission tariff of PJM Interconnection LLC (PJM), unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. Starting in January 2014, PJM submitted to the FERC a series of requests that substantially increase the charges for the transmission service. CECONY has challenged each of these requests. To date, FERC has rejected all but one of CECONY’s protests. In April 2016, CECONY notified PJM that it will not be exercising its option to continue the service beyond April 2017. CECONY is continuing to challenge FERC’s approval of the increased charges that are being incurred through the end of the current contract term. In June 2015 and May 2016, CECONY filed appeals of certain FERC decisions with the U.S. Court of Appeals.

(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 (5.0, 7.5 or 10.0 basis points, depending on the year).

(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 of 30 percent of the amount reflected in rates.

(g) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers.

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CECONY – Gas
Effective period	January 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(54.6) million (a) Yr. 2 – $38.6 million (a) Yr. 3 – $56.8 million (a)	Yr. 1 - $(5) million (b) Yr. 2 - $92 million (b) Yr. 3 - $90 million (b)
Amortizations to income of net regulatory (assets) and liabilities	$4 million over three years	Yr. 1 - $39 million Yr. 2 - $37 million Yr. 3 - $36 million
Other revenue sources	Retention of revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. The company retained $70 million, $66 million and $65 million of such revenues in 2014, 2015 and 2016, respectively.	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.
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred $28 million, $54 million and $71 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $33 million in 2014, $44 million in 2015, and $56 million in 2016) if certain gas performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 - $68 million Yr. 2 - $75 million Yr. 3 - $83 million.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $38 million, $11 million, and $32 million of net regulatory liabilities, respectively. (c)	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(d)
Net utility plant reconciliations	Target levels reflected in rates were: Gas delivery Yr. 1 – $3,899 million; Yr. 2 – $4,258 million; Yr. 3 – $4,698 million Storm hardening: Yr. 1 – $3 million; Yr. 2 – $8 million; Yr. 3 – $30 million In 2015 $1 million was deferred as a regulatory liability. In 2014 and 2016 the company deferred an immaterial amount.	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
Average rate base	Yr. 1 – $3,521 million Yr. 2 – $3,863 million Yr. 3 – $4,236 million	Yr. 1 - $4,841 million Yr. 2 - $5,395 million Yr. 3 - $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.3 percent	9.0 percent
Earnings sharing	Most 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, 2015 and 2016, the company had no earnings above the threshold.	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.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $32 million regulatory liability at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's gas rate plan for January 2017 through December 2019. The gas base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(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) See footnotes (e), (f) and (g) to the table under "CECONY - Electric" above.

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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
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 penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015 and 2016, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets and $8 million of net regulatory liabilities, 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.
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
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.
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.

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O&R New York – Electric
Effective period	July 2012 – June 2015	November 2015 - October 2017
Base rate changes	Yr. 1 – $19.4 million Yr. 2 – $8.8 million Yr. 3 – $15.2 million	Yr. 1 – $9.3 million Yr. 2 – $8.8 million
Amortizations to income of net regulatory (assets) and liabilities	$(32.2) million over three years	Yr. 1 – $(8.5) million (a) Yr. 2 – $(9.4) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred for the customer’s benefit $2.6 million, $3.2 million and $(3.4) million, respectively.	In 2015 and 2016, the company deferred for the customer’s benefit an immaterial amount and $6.3 million as regulatory liabilities, respectively.
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential penalties (up to $3 million annually) if certain customer service and system reliability performance targets are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (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, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase/(decrease) to regulatory assets, respectively.	In 2015 and 2016, the company deferred $0.3 million and $7.4 million as net decreases to regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Yr. 1 – $678 million; Yr. 2- $704 million; Yr. 3 – $753 million The company increased its regulatory liability by $4.2 million in 2012. The company reduced its regulatory liability by $1.1 million and $2.3 million in 2013 and 2014, respectively.	Target levels reflected in rates are: Yr. 1 – $928 million (b) Yr. 2 – $970 million (b) The company increased/(reduced) its regulatory asset by $2.2 million and $(1.9) million in 2015 and 2016, respectively.
Average rate base	Yr. 1 – $671 million Yr. 2 – $708 million Yr. 3 – $759 million	Yr. 1 – $763 million Yr. 2 – $805 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.61 percent Yr. 2 – 7.65 percent Yr. 3 – 7.48 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent
Authorized return on common equity	Yr. 1 – 9.4 percent Yr. 2 – 9.5 percent Yr. 3 – 9.6 percent	9.0 percent
Earnings sharing	The company recorded a regulatory liability of $1 million for earnings above the sharing threshold under the rate plan as of December 31, 2014.	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 above the threshold for 2016.
Cost of long-term debt	Yr. 1 – 6.07 percent Yr. 2 – 6.07 percent Yr. 3 – 5.64 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a five 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.

(b) 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.

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O&R New York – Gas
Effective period	November 2009 – December 2014	November 2015 – October 2018
Base rate changes	Yr. 1 – $9 million Yr. 2 – $9 million Yr. 3 – $4.6 million Yr. 3 – $4.3 million collected through a surcharge Yr. 4 – None Yr. 5 – None	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge
Amortization to income of net regulatory (assets) and liabilities	$(2) million over three years	Yr. 1 – $(1.7) million (a) Yr. 2 – $(2.1) million (a) Yr. 3 – $(2.5) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred $4.7 million, $0.7 million and $(0.1) million of regulatory liabilities, respectively.	In 2015 and 2016, the company deferred $0.8 million regulatory assets and $6.2 million of regulatory liabilities, respectively.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $1.4 million annually) if certain operations and customer service requirements are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $5.8 million in Yr. 3) if certain performance targets are not met. In 2015 and 2016, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $0.7 million, $8.3 million and $8.3 million as net regulatory assets, respectively.	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively.
Net utility plant reconciliations	The company deferred $0.7 million in 2012 as a regulatory asset and no deferrals were recorded for 2013 or 2014.	Target levels reflected in rates are: Yr. 1 – $492 million (b) Yr. 2 – $518 million (b) Yr. 3 – $546 million (b) No deferral was recorded for 2015 and an immaterial amount was recorded as a regulatory liability in 2016.
Average rate base	Yr. 1 – $280 million Yr. 2 – $296 million Yr. 3 – $309 million	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million
Weighted average cost of capital (after-tax)	8.49 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent
Authorized return on common equity	10.4 percent	9.0 percent
Earnings sharing	Earnings above an annual earnings threshold of 11.4 percent are to be applied to reduce regulatory assets. In 2012, 2013 and 2014, 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. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million above the threshold for 2016.
Cost of long-term debt	6.81 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) 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.

(b) 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.

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RECO
Effective period	May 2010 – July 2014	August 2014 – July 2015 (a)
Base rate changes	Yr. 1 – $9.8 million	Yr. 1 – $13.0 million
Amortization to income of net regulatory (assets) and liabilities	$(3.9) million over four years and $(4.9) million of deferred storm costs over five years	$0.4 million over three years and $(25.6) million of deferred storm costs 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	$148.6 million	$172.2 million
Weighted average cost of capital (after-tax)	8.21 percent	7.83 percent
Authorized return on common equity	10.3 percent	9.75 percent
Cost of long-term debt	6.16 percent	5.89 percent
Common equity ratio	50 percent	50 percent

(a) In January 2016, the NJBPU approved RECO’s plan for a 3-year, $15.7 million electric system storm hardening capital program, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge until a new rate plan is approved that reflects the costs.

In February 2017, RECO, the staff of the NJBPU and other parties entered into a stipulation of settlement for a RECO electric rate plan for the period commencing March 2017. The stipulation is subject to NJBPU approval. The rate plan would provide for an electric rate increase of $1.7 million, reflecting a return on common equity of 9.6 percent and a common equity ratio of 49.7 percent, and for continuation of the provisions for recovery from customers of the cost of purchased power.

In January 2017, RECO filed a request with FERC for an increase to its annual transmission revenue requirement from $11.8 million to $19.7 million, effective April 2017. The filing reflects a return on common equity of 10.7 percent and a common equity ratio of 48 percent.

Other Regulatory Matters

In June 2014, the NYSPSC initiated a proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. New York State regulations require gas utilities to qualify and, except in certain circumstances, annually requalify workers that perform fusion to join plastic pipe. The NYSPSC directed the New York gas utilities to provide information in this proceeding about their compliance with the qualification and requalification requirements and related matters; their procedures for compliance with all gas safety regulations; and their annual chief executive officer certifications regarding these and other procedures. CECONY’s qualification and requalification procedures had not included certain required testing to evaluate specimen fuses. In addition, CECONY and O&R had not timely requalified certain workers that had been qualified under their respective procedures to perform fusion to join plastic pipe. CECONY and O&R have requalified their workers who perform plastic pipe fusions. In May 2015, the NYSPSC, which indicated that it would address enforcement at a later date, ordered CECONY, O&R and other gas utilities to perform risk assessment and remediation plans, additional leakage surveying and reporting; CECONY to hire an independent statistician to develop a risk assessment and remediation plan; and the gas utilities to implement certain new plastic fusion requirements. In December 2015, the NYSPSC staff informed O&R that the company had satisfactorily completed its risk assessment and remediation plan. CECONY is implementing the three-year risk assessment and remediation plan it submitted to the NYSPSC staff in October 2016.

In November 2015, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence proceedings to penalize the company for alleged violations of gas safety regulations identified by the NYSPSC staff in its investigation of a March 2014 explosion and fire and to review the prudence of the company's conduct associated with the incident. See "Manhattan Explosion and Fire" in Note H. In December 2015, the company responded that the NYSPSC should not institute the proceedings and disputed the alleged violations.

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In February 2017, the NYSPSC approved a settlement agreement with CECONY related to the June 2014 plastic fusion proceeding and the November 2015 order to show cause. Pursuant to the settlement agreement, the company will not recover from customers $126 million of costs it incurred for gas emergency response activities in 2014, 2015 and 2016 in excess of amounts reflected in its gas rate plan for those years. At December 31, 2016, the company had not deferred any such incremental costs as a regulatory asset. In addition, the company will provide $27 million of future benefits to customers. At December 31, 2016, the Company had accrued a regulatory liability for these future benefits.

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Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2016 and 2015 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$2,874	$3,876	$2,730	$3,697
Future income tax	2,439	2,350	2,325	2,232
Environmental remediation costs	823	904	711	800
Revenue taxes	295	253	280	240
Deferred storm costs	56	185	3	110
Deferred derivative losses	48	50	42	46
Unamortized loss on reacquired debt	43	50	41	48
Recoverable energy costs	42	16	38	15
Pension and other postretirement benefits deferrals	38	45	7	16
O&R property tax reconciliation	37	46	—	—
Surcharge for New York State assessment	28	44	26	40
Preferred stock redemption	25	26	25	26
Net electric deferrals	24	44	24	44
O&R transition bond charges	15	21	—	—
Workers’ compensation	13	11	13	11
Other	224	175	208	157
Regulatory assets – noncurrent	7,024	8,096	6,473	7,482
Deferred derivative losses	91	113	86	103
Recoverable energy costs	9	19	4	18
Regulatory assets – current	100	132	90	121
Total Regulatory Assets	$7,124	$8,228	$6,563	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$755	$676	$641	$570
Pension and other postretirement benefit deferrals	193	76	162	46
Property tax reconciliation	178	303	178	303
Net unbilled revenue deferrals	145	109	145	109
Prudence proceeding	95	99	95	99
Carrying charges on repair allowance and bonus depreciation	68	49	67	48
New York State income tax rate change	61	75	60	72
Unrecognized other postretirement costs	60	28	60	28
Variable-rate tax-exempt debt - cost rate reconciliation	55	70	48	60
Base rate change deferrals	40	128	40	128
Earnings sharing - electric, gas and steam	39	80	28	80
Net utility plant reconciliations	16	32	15	31
Property tax refunds	1	44	1	44
World Trade Center settlement proceeds	—	21	—	21
Other	199	187	172	150
Regulatory liabilities – noncurrent	1,905	1,977	1,712	1,789
Revenue decoupling mechanism	71	45	61	45
Refundable energy costs	29	64	5	33
Deferred derivative gains	28	6	24	6
Regulatory liabilities—current	128	115	90	84
Total Regulatory Liabilities	$2,033	$2,092	$1,802	$1,873

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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.

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

Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Superstorm Sandy and other major storms that were deferred by the Utilities.

Net electric deferrals represent the remaining unamortized balance of certain regulatory assets and liabilities of CECONY that were combined effective April 1, 2010 and are being amortized to income through March 31, 2018.

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

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 $145 million and $109 million at December 31, 2016 and 2015, respectively, for the difference between the unbilled revenues and energy cost liabilities.

Note C – Capitalization

Common Stock

At December 31, 2016 and 2015, Con Edison owned all of the issued and outstanding shares of common stock of the Utilities, the Clean Energy Businesses and Con Edison Transmission. CECONY owns 21,976,200 shares of Con Edison stock, which it purchased prior to 2001 in connection with Con Edison’s stock repurchase plan. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity.

Capitalization of Con Edison

The outstanding capitalization for each of the Companies is shown on its Consolidated Statement of Capitalization, and for Con Edison includes outstanding 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. 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 2017-2021 is as follows:

(Millions of Dollars)	Con Edison	CECONY
2017	$39		$—
2018	1,688	1,200
2019	574	475
2020	388	350
2021	540	—

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.

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The carrying amounts and fair values of long-term debt at December 31, 2016 and 2015 are:

(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,774	$16,093	$12,745	$13,856
CECONY	$12,073	$13,268	$11,437	$12,427

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $15,457 million and $636 million of the fair value of long-term debt at December 31, 2016 are classified as Level 2 and Level 3, respectively. For CECONY, $12,632 million and $636 million of the fair value of long-term debt at December 31, 2016 are classified as Level 2 and Level 3, respectively (see Note P). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

At December 31, 2016 and 2015, long-term debt of Con Edison included $845 million and $339 million, respectively, of non-recourse debt secured by the pledge of the applicable renewable energy production projects of the Clean Energy Businesses. At December 31, 2016 and 2015, long-term debt of Con Edison included $11 million and $15 million, respectively, of Transition Bonds issued in 2004 by O&R’s New Jersey utility subsidiary through a special purpose entity.

Significant Debt Covenants

The significant debt covenants under the financing arrangements for the Companies' debentures and Con Edison's notes and term loan include obligations to pay principal and interest when due and covenants not to consolidate with or merge into any other corporation 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 capital to exceed certain amounts (0.675 to 1 for the notes and 0.65 to 1 for the term loan) and include cross default provisions with respect to other indebtedness of the company or its subsidiaries (material subsidiaries, in the case of the notes) having a then outstanding principal balance in excess of certain amounts ($100 million for the notes and $150 million for the term loan). 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, 2016.

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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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 expires in December 2021. There is a maximum of $2,250 million of credit available. 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, 2016, Con Edison had $1,054 million of commercial paper outstanding, of which $600 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2016 was 1.0 percent for both Con Edison and CECONY. At December 31, 2015, Con Edison had $1,529 million of commercial paper outstanding of which $1,033 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2015 was 0.7 percent for both Con Edison and CECONY. At December 31, 2016 and 2015, no loans were outstanding under the Credit Agreement and $2 million (including $2 million for CECONY) and $15 million of letters of credit were outstanding under the Credit Agreement, respectively.

The banks’ commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2016 this ratio was 0.51 to 1 for Con Edison and 0.52 to 1 for CECONY); having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings. The Companies were in compliance with their covenants at December 31, 2016.

See Note S 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 and O&R 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. In addition, Con Edison maintains additional non-qualified supplemental pension plans.

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit costs for 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Service cost – including administrative expenses	$275	$297	$227	$258	$279	$211
Interest cost on projected benefit obligation	596	575	572	559	538	536
Expected return on plan assets	(947)	(886)	(832)	(898)	(840)	(789)
Recognition of net actuarial loss	596	775	618	565	734	586
Recognition of prior service costs	4	4	4	2	2	2
NET PERIODIC BENEFIT COST	$524	$765	$589	$486	$713	$546
Amortization of regulatory asset (a)	—	1	2	—	1	2
TOTAL PERIODIC BENEFIT COST	$524	$766	$591	$486	$714	$548
Cost capitalized	(214)	(301)	(225)	(203)	(285)	(212)
Reconciliation to rate level	54	(74)	118	58	(74)	108
Cost charged to operating expenses	$364	$391	$484	$341	$355	$444

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

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Funded Status

The funded status at December 31, 2016, 2015 and 2014 was as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$14,377	$15,081	$12,197	$13,482	$14,137	$11,429
Service cost – excluding administrative expenses	271	293	221	254	274	206
Interest cost on projected benefit obligation	596	575	572	559	538	536
Net actuarial (gain)/loss	(302)	(996)	2,641	(282)	(931)	2,484
Plan amendments	(256)	—	6	(259)	—	—
Benefits paid	(591)	(576)	(556)	(551)	(536)	(518)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$14,095	$14,377	$15,081	$13,203	$13,482	$14,137
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$11,759	$11,495	$10,755	$11,141	$10,897	$10,197
Actual return on plan assets	829	126	752	787	118	715
Employer contributions	508	750	578	469	697	535
Benefits paid	(591)	(576)	(556)	(551)	(536)	(518)
Administrative expenses	(33)	(36)	(34)	(31)	(35)	(32)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$12,472	$11,759	$11,495	$11,815	$11,141	$10,897
FUNDED STATUS	$(1,623)	$(2,618)	$(3,586)	$(1,388)	$(2,341)	$(3,240)
Unrecognized net loss	$3,157	$3,909	$4,888	$2,995	$3,704	$4,616
Unrecognized prior service costs	(244)	16	20	(258)	3	4
Accumulated benefit obligation	12,655	12,909	13,454	11,806	12,055	12,553

The decrease in the pension plan’s projected benefit obligation was the primary cause of the decreased pension liability at Con Edison and CECONY of $995 million and $953 million, respectively, compared with December 31, 2015. For Con Edison, this decrease in pension liability corresponds with a decrease to regulatory assets of $1,002 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 $5 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 the Clean Energy Businesses and RECO.

For CECONY, the decrease in pension liability corresponds with a decrease to regulatory assets of $967 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, a credit to OCI of $1 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 the Clean Energy Businesses.

A portion of the unrecognized net loss and prior service cost for the pension plan, equal to $579 million and $(16) million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $548 million and $(18) million, respectively, for CECONY.

At December 31, 2016 and 2015, Con Edison’s investments include $273 million and $243 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $246 million and $221 million, respectively. See Note P. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $303 million and $268 million as of December 31, 2016 and $285 million and $249 million as of December 31, 2015, respectively.

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Assumptions

The actuarial assumptions were as follows:

	2016		2015		2014
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate	4.25	%	4.25	%	3.90	%
Rate of compensation increase
CECONY	4.25	%	4.25	%	4.25	%
O&R	4.00	%	4.00	%	4.00	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.25	%	3.90	%	4.80	%
Expected return on plan assets	7.80	%	7.80	%	8.00	%
Rate of compensation increase
CECONY	4.25	%	4.25	%	4.35	%
O&R	4.00	%	4.00	%	4.25	%

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

Discount Rate Assumption

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

Expected Benefit Payments

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

(Millions of Dollars)	2017	2018	2019	2020	2021	2022-2026
Con Edison	$702	$719	$730	$745	$758	$3,990
CECONY	653	670	679	693	705	3,716

Expected Contributions

Based on estimates as of December 31, 2016, the Companies expect to make contributions to the pension plans during 2017 of $423 million (of which $388 million is to be contributed 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 2016, 2015 and 2014, and the target allocation for 2017 are as follows:

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	Target Allocation Range	Plan Assets at December 31,
Asset Category	2017	2016		2015		2014
Equity Securities	52% - 64%	58	%	57	%	58	%
Debt Securities	28% - 38%	33	%	33	%	32	%
Real Estate	7% - 11%	9	%	10	%	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 2017 reflects the results of such a study conducted in 2016.

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.

In May 2015, the FASB issued ASU 2015-07, Fair Value Measurements (Topic 820):Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), which exempts investments measured using net asset value (NAV) practical expedient in ASC 820, Fair Value Measurement, from categorization within the fair value hierarchy. The guidance requires retrospective application and is effective for public business entities for fiscal years, and interim periods within those years, beginning after December 15, 2015. Accordingly, the amendment was retrospectively applied, resulting in the reclassification of real estate funds, private equity and hedge fund investments from Level III assets on the fair value hierarchy to investments measured at net asset value.

Assets measured at fair value on a recurring basis are summarized below as defined by the accounting rules for fair value measurements (see Note P).

The fair values of the pension plan assets at December 31, 2016 by asset category are as follows:

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(Millions of Dollars)	Level 1	Level 2		Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,466		$—	$3,466
International Equity (b)	3,187	371		3,558
U.S. Government Issued Debt (c)	—	1,337		1,337
Corporate Bonds Debt (d)	—	2,140		2,140
Structured Assets Debt (e)	—	1		1
Other Fixed Income Debt (f)	—	200		200
Cash and Cash Equivalents (g)	147	389		536
Futures (h)	296	68		364
Total investments within the fair value hierarchy	$7,096	$4,506		$11,602
Investments measured at NAV per share (n)
Private Equity (i)				247
Real Estate (j)				1,139
Hedge Funds (k)				229
Total investments valued using NAV per share				$1,615
Funds for retiree health benefits (l)	(165)	(105)		(270)
Funds for retiree health benefits measured at NAV per share (l)(n)				(37)
Total funds for retiree health benefits				$(307)
Investments (excluding funds for retiree health benefits)	$6,931	$4,401		$12,910
Pending activities (m)				(438)
Total fair value of plan net assets				$12,472

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

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

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

(k) Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.

(l) 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.

(m) 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.

(n) In accordance with ASU 2015-07, 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.

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The fair values of the pension plan assets at December 31, 2015 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2		Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,106		$—	$3,106
International Equity (b)	2,874	346		3,220
U.S. Government Issued Debt (c)	—	2,222		2,222
Corporate Bonds Debt (d)	—	1,356		1,356
Structured Assets Debt (e)	—	1		1
Other Fixed Income Debt (f)	—	170		170
Cash and Cash Equivalents (g)	115	414		529
Futures (h)	161	132		293
Total investments within the fair value hierarchy	$6,256	$4,641		$10,897
Investments measured at NAV per share (n)
Private Equity (i)				170
Real Estate (j)				1,248
Hedge Funds (k)				233
Total investments valued using NAV per share				$1,651
Funds for retiree health benefits (l)	(162)	(120)		(282)
Funds for retiree health benefits measured at NAV per share (l)(n)				(43)
Total funds for retiree health benefits				$(325)
Investments (excluding funds for retiree health benefits)	$6,094	$4,521		$12,223
Pending activities (m)				(464)
Total fair value of plan net assets				$11,759

(a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2016 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)	2016	2015	2014
Con Edison	$36	$34	$32
CECONY	32	29	27

Mortality Table Revision

The Companies adopted revised mortality tables effective December 31, 2014 in the measurement of its pension and other postretirement benefit plan obligations, accounting costs and required contribution amounts. The revised tables reflect the RP-2014 mortality tables published by the Society of Actuaries in October 2014, as adjusted based on the actual experience of the Companies. The new tables incorporate substantial life expectancy improvements relative to the last tables published in 2000 (RP-2000). As a result of the adoption, Con Edison recognized an increase in its pension benefit obligation of approximately $800 million as of December 31, 2014. The Companies, under their current New York rate plans, defer as a regulatory asset or liability, as the case may be, the differences between the actual level of expenses for pension and other postretirement benefits and amounts for those expenses reflected in rates.

Note F – Other Postretirement Benefits

The Utilities 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

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non-contributory life insurance program for retirees. Certain employees of the Clean Energy Businesses are eligible to receive benefits under these programs.

Total Periodic Benefit Cost

The components of the Companies’ total periodic postretirement benefit costs for 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Service cost	$18	$20	$19	$13	$15	$15
Interest cost on accumulated other postretirement benefit obligation	48	51	60	40	43	52
Expected return on plan assets	(77)	(78)	(77)	(67)	(68)	(68)
Recognition of net actuarial loss	5	31	57	3	28	51
Recognition of prior service cost	(20)	(20)	(19)	(14)	(14)	(15)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST	$(26)	$4	$40	$(25)	$4	$35
Cost capitalized	11	(2)	(15)	10	(2)	(14)
Reconciliation to rate level	22	14	10	22	6	2
Cost charged to operating expenses	$7	$16	$35	$7	$8	$23

Funded Status

The funded status of the programs at December 31, 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$1,287	$1,411	$1,395	$1,093	$1,203	$1,198
Service cost	18	20	19	13	15	15
Interest cost on accumulated postretirement benefit obligation	48	51	60	40	43	52
Amendments	—	—	(12)	—	—	—
Net actuarial loss/(gain)	(57)	(103)	47	(52)	(85)	28
Benefits paid and administrative expenses	(134)	(127)	(134)	(122)	(117)	(125)
Participant contributions	36	35	36	35	34	35
BENEFIT OBLIGATION AT END OF YEAR	$1,198	$1,287	$1,411	$1,007	$1,093	$1,203
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$994	$1,084	$1,113	$870	$950	$977
Actual return on plan assets	60	(6)	59	52	(4)	54
Employer contributions	7	6	7	7	6	7
EGWP payments	35	28	12	33	26	11
Participant contributions	36	35	36	35	34	35
Benefits paid	(157)	(153)	(143)	(146)	(142)	(134)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$975	$994	$1,084	$851	$870	$950
FUNDED STATUS	$(223)	$(293)	$(327)	$(156)	$(223)	$(253)
Unrecognized net loss/(gain)	$(24)	$28	$78	$(42)	$4	$45
Unrecognized prior service costs	(31)	(51)	(71)	(18)	(32)	(46)

The decrease in the other postretirement benefit plan obligation was the primary cause of the decreased liability for other postretirement benefits at Con Edison and CECONY of $70 million and $67 million, respectively, compared with December 31, 2015. For Con Edison, this decreased liability corresponds with an increase to regulatory liabilities of $32 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 a debit to OCI of $1 million (net of taxes) for the unrecognized prior service costs associated with the Clean Energy Businesses and RECO.

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For CECONY, the decrease in liability corresponds with an increase to regulatory liabilities of $32 million for unrecognized net losses and unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, and a credit to OCI of $1 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 the Clean Energy Businesses.

A portion of the unrecognized net losses and prior service costs for the other postretirement benefits, equal to $4 million and $(17) million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $1 million and $(11) million, respectively, for CECONY.

Assumptions

The actuarial assumptions were as follows:

	2016		2015		2014
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY	4.00	%	4.05	%	3.75	%
O&R	4.20	%	4.20	%	3.85	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate
CECONY	4.05	%	3.75	%	4.50	%
O&R	4.20	%	3.85	%	4.75	%
Expected Return on Plan Assets	7.00	%	7.75	%	7.75	%

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 year ended December 31, 2016 was 6.00 percent, which is 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, 2016 was 5.80 percent, which is assumed to decrease gradually to 4.50 percent by 2024 and remain at that level thereafter.

A one-percentage point change in the assumed health care cost trend rate would have the following effects at December 31, 2016:

	Con Edison		CECONY
	1-Percentage-Point
(Millions of Dollars)	Increase	Decrease	Increase	Decrease
Effect on accumulated other postretirement benefit obligation	$(4)	$26	$(24)	$41
Effect on service cost and interest cost components for 2016	1	—	(1)	1

Expected Benefit Payments

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

(Millions of Dollars)	2017	2018	2019	2020	2021	2022-2026
Con Edison	$86	$85	$83	$80	$78	$375
CECONY	77	75	73	70	68	322

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Expected Contributions

Based on estimates as of December 31, 2016, Con Edison and CECONY expect to make a contribution of $14 million (of which $10 million is to be contributed by CECONY) to the other postretirement benefit plans in 2017. 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 2016, 2015 and 2014, and the target allocation for 2017 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2017	2016		2015		2014
Equity Securities	57%-73%	60	%	59	%	59	%
Debt Securities	26%-44%	40	%	41	%	41	%
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 plan assets at December 31, 2016 by asset category as defined by the accounting rules for fair value measurements (see Note P) are as follows:

(Millions of Dollars)	Level 1		Level 2	Total
Equity (a)		$—	$391	$391
Other Fixed Income Debt (b)	—		250	250
Cash and Cash Equivalents (c)	—		13	13
Total investments		$—	$654	$654
Funds for retiree health benefits (d)	165		105	270
Investments (including funds for retiree health benefits)	$165		$759	$924
Funds for retiree health benefits measured at net asset value (d)(e)				37
Pending activities (f)				14
Total fair value of plan net assets				$975

(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 Barclays Capital Aggregate 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, 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. See Note E.

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

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The fair values of the plan assets at December 31, 2015 by asset category (see Note P) are as follows:

(Millions of Dollars)	Level 1		Level 2	Total
Equity (a)		$—	$393	$393
Other Fixed Income Debt (b)	—		260	260
Cash and Cash Equivalents (c)	—		7	7
Total investments		$—	$660	$660
Funds for retiree health benefits (d)	162		120	282
Investments (including funds for retiree health benefits)	$162		$780	$942
Funds for retiree health benefits measured at net asset value (d)(e)				43
Pending activities (f)				9
Total fair value of plan net assets				$994

(a) - (f) Reference is made to footnotes (a) through (f) in the above table of other postretirement benefit plan assets at December 31, 2016 by asset category.

Mortality Table Revision

The Companies adopted revised mortality tables effective December 31, 2014 in the measurement of its pension and other postretirement benefit plan obligations, accounting costs, and required contribution amounts as discussed in Note E. As a result of the adoption, Con Edison recognized an increase of less than $10 million in its other postretirement benefits obligation as of December 31, 2014. The Companies, under their current New York rate plans, defer as a regulatory asset or liability, as the case may be, the differences between the actual level of expenses for pension and other postretirement benefits and amounts for those expenses reflected in rates.

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, 2016 and 2015 were as follows:

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	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$664	$679	$567	$579
Other Superfund Sites	89	86	88	86
Total	$753	$765	$655	$665
Regulatory assets	$823	$904	$711	$800

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 and insurance recoveries received related to Superfund Sites at December 31, 2016 and 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$34	$37	$21	$34
Insurance recoveries received (a)	1	—	1	—

(a) Reduced amount deferred for recovery from customers

Con Edison and CECONY estimate that in 2017 they will incur costs for remediation of approximately $55 million and $47 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 2016, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $2.8 billion and $2.6 billion, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different.

Asbestos Proceedings

Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, which are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At December 31, 2016, 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.

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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, 2016 and 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$88	$86	$83	$81
Regulatory assets – workers’ compensation	$13	$11	$13	$11

Note H – Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately sixty suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs to satisfy its liability to others in connection with the suits. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At December 31, 2016, the company has accrued its estimated liability for the suits of $25 million and an insurance receivable of $25 million.

Manhattan Explosion and Fire

On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th Street 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 (which also conducted an investigation). 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. Approximately seventy suits are pending against the company seeking generally unspecified damages and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have for damages in connection with the incident. The company is unable to estimate the amount or range of its possible loss for damages related to the incident. At December 31, 2016, the company had not accrued a liability for damages related to the incident.

Other Contingencies

See “Other Regulatory Matters” in Note B and "Uncertain Tax Positions" in Note L.

Guarantees

Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled $2,370 million and $2,856 million at December 31, 2016 and 2015, respectively.

A summary, by type and term, of Con Edison’s total guarantees at December 31, 2016 is as follows:

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Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$435	$613		$—	$1,048
Energy transactions	603	35	98		736
Renewable electric production projects	439	—	19		458
Other	128	—	—		128
Total	$1,605	$648	$117		$2,370

Con Edison Transmission – Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric acquired a 45.7 percent interest in NY Transco when it was formed in 2014. In May 2016, the transmission owners transferred certain projects to NY Transco, as to which CET Electric made its required contributions. The other projects that were proposed when NY Transco was formed remain subject to certain authorizations from the NYSPSC, the FERC and, as applicable, other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of CET Electric's contributions for these other projects as calculated based on the assumptions that the projects are completed at 175 percent of their estimated costs and NY Transco does not use any debt financing for the projects. Guarantee term shown is assumed as the timing of the contributions is not certain. Also included within the table above is a guarantee for $25 million from Con Edison on behalf of CET Gas in relation to a proposed gas transmission project in West Virginia and Virginia. See Note U.

Energy Transactions — Con Edison guarantees payments on behalf of the Clean Energy Businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Guarantee amounts shown above include $42 million of guarantees or other credit support provided by Con Edison on behalf of Con Edison Solutions that may continue in effect during the period in which Con Edison Solutions provides transition services in connection with the retail electric supply business it sold in September 2016. See Note U. As part of the sale agreement, the purchaser has agreed to pay Con Edison Solutions for draws on such guarantees or other credit support.

Renewable Electric Production Projects – Con Edison, Con Edison Development and Con Edison Solutions guarantee payments associated with the investment in solar and wind energy facilities on behalf of their wholly-owned subsidiaries.

Other – Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with operation of solar energy facilities and energy service projects of Con Edison Development and Con Edison Solutions, respectively. Other guarantees also includes Con Edison's guarantee (subject to a $53 million maximum amount) of certain obligations of Con Edison Solutions under its agreement to sell its retail electric supply business. See Note U. In addition, Con Edison issued a guarantee estimated at $5 million to the Public Utility Commission of Texas covering obligations of Con Edison Solutions as a retail electric provider. As part of the sale agreement for the retail electric supply business discussed above, the purchaser has agreed to pay Con Edison Solutions for draws on the guarantee to the Public Utility Commission of Texas.

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.

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At December 31, 2016, the significant terms of the electricity purchase agreements with non-utility generators were as follows:

Facility	Equity Owner	Plant Output (MW)	Contracted Output (MW)	Contract Start Date	Contract Term (Years)
Brooklyn Navy Yard	Brooklyn Navy Yard Cogeneration Partners, LP	322	293	November 1996	40
Linden Cogeneration	Cogen Technologies Linden Venture, LP	974	630	May 1992	25
Indian Point	Entergy Nuclear Power Marketing, LLC	2,150	500	August 2001	16

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 contracts are estimated to be as follows:

(Millions of Dollars)	2017	2018	2019	2020	2021	All Years Thereafter
Con Edison	$178	$125	$120	$76	$54	$710
CECONY	178	125	119	75	54	710

For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the agreements for capacity, energy and other fixed payments in 2016, 2015 and 2014 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
Linden Cogeneration	$304	$323	$381
Indian Point	203	226	247
Astoria Energy (a)	50	178	230
Astoria Generating Company	16	—	—
Brooklyn Navy Yard	119	113	133
Indeck Corinth (b)	—	25	80
Selkirk (c)	—	—	144
Independence (c)	—	—	97
Total	$692	$865	$1,312

(a) Contract term ended in 2016.

(b) Contract term ended in 2015.

(c) Contract term ended in 2014

Note J – Leases

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

Capital leases: For ratemaking purposes capital leases are treated as operating leases; therefore, in accordance with the accounting rules for regulated operations, the amortization of the leased asset is based on the rental payments recovered from customers. The following assets under capital leases are included in the Companies’ consolidated balance sheets at December 31, 2016 and 2015:

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	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
UTILITY PLANT
Common	$3	$3	$2	$2

The accumulated amortization of the capital leases for Con Edison and CECONY was $3 million and $1 million, respectively at December 31, 2016, and $3 million and $2 million, respectively at December 31, 2015.

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

(Millions of Dollars)	Con Edison	CECONY
2017	$1	$1
2018	1	1
2019	—	—
2020	—	—
2021	—	—
All years thereafter	—	—
Total	2	2
Less: amount representing interest	—	—
Present value of net minimum lease payment	$2	$2

Operating leases: The future minimum lease commitments under the Companies’ operating lease agreements that are not cancellable by the Companies are as follows:

(Millions of Dollars)	Con Edison	CECONY
2017	$61	$53
2018	62	54
2019	61	54
2020	61	54
2021	58	53
All years thereafter	788	696
Total	$1,091	$964

Substantially all of the amounts shown in the above table are estimated amounts payable under CECONY’s revocable consent agreement with New York City for the use of streets and public places for installation and operation of transformers and associated vaults and equipment. Under the agreement, payments by CECONY increase 2.18 percent annually and are subject to decrease if CECONY’s transformer installations decrease by ½ of 1 percent or more from the prior year.

For information about changes to the accounting rules for leases, see Note T.

Note K – Goodwill and Other Intangible Assets

In 2016 and 2015, Con Edison completed impairment tests for its goodwill of $406 million related to the O&R merger, and determined that it was not impaired. For the impairment test, $245 million and $161 million of the goodwill were allocated to CECONY and O&R, respectively. In 2016 and 2015, Con Edison completed impairment tests for the goodwill of $23 million related to two energy services companies owned by Con Edison Solutions and a gas storage company owned by Con Edison Development. In 2015, Con Edison determined that the goodwill was not impaired. In 2016, Con Edison determined that goodwill related to the two energy services companies was impaired and upon calculating the implied fair value of goodwill using fair values based primarily on discounted cash flows, recorded a corresponding impairment charge of $15 million ($12 million, net of tax). In 2016, Con Edison determined that goodwill related to the gas storage company was not impaired. Additionally, in 2016, Con Edison Solutions acquired a residential solar company and recorded $14 million of goodwill as part of the preliminary

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purchase price allocation. Estimates of future cash flows, projected growth rates, and discount rates inherent in the cash flow estimates for the gas storage company and residential solar company may vary significantly from actual results, which could result in a future impairment of goodwill.

For information about changes to the accounting rules for goodwill, see Note T.

Con Edison's other intangible assets consist primarily of power purchase agreements, which were identified as part of purchase price allocations associated with acquisitions made by Con Edison Development in 2016 (see Note U). At December 31, 2016, intangible assets arising from power purchase agreements were $119 million, net of accumulated amortization of $1 million, and are being amortized over the life of each agreement. Excluding power purchase agreements, Con Edison’s other intangible assets were $5 million and $2 million, net of accumulated amortization of $5 million and $4 million, at December 31, 2016 and 2015, respectively. CECONY’s other intangible assets were immaterial at December 31, 2016 and 2015. Con Edison recorded amortization expense related to its intangible assets of $2 million in 2016, and immaterial amounts in 2015 and 2014. Con Edison expects amortization expense to be $8 million per year over the next five years.

Note L – Income Tax

The components of income tax are as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
State
Current	$(42)	$38	$59	$(1)	$48	$66
Deferred	188	93	61	114	82	65
Federal
Current	(43)	(86)	(9)	59	77	158
Deferred	604	569	463	435	372	271
Amortization of investment tax credits	(9)	(9)	(6)	(4)	(5)	(5)
Total income tax expense	$698	$605	$568	$603	$574	$555

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Deferred tax liabilities:
Property basis differences	$9,446	$8,614	$8,620	$7,922
Regulatory assets:
Unrecognized pension and other postretirement costs	1,162	1,562	1,104	1,490
Future income tax	986	947	940	899
Environmental remediation costs	333	365	287	322
Deferred storm costs	23	75	1	45
Other regulatory assets	371	367	321	308
Equity investments	363	295	—	—
Total deferred tax liabilities	$12,684	$12,225	$11,273	$10,986
Deferred tax assets:
Accrued pension and other postretirement costs	$581	$982	$467	$857
Regulatory liabilities	822	836	728	752
Superfund and other environmental costs	304	308	265	268
Asset retirement obligations	99	97	92	94
Loss carryforwards	59	29	—	—
Tax credits carryforward	498	258	—	1
Valuation allowance	(16)	(15)	—	—
Other	303	362	312	292
Total deferred tax assets	2,650	2,857	1,864	2,264
Net deferred tax liabilities	$10,034	$9,368	$9,409	$8,722
Unamortized investment tax credits	171	169	41	33
Net deferred tax liabilities and unamortized investment tax credits	$10,205	$9,537	$9,450	$8,755

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)	2016		2015		2014		2016		2015		2014
STATUTORY TAX RATE
Federal	35	%	35	%	35	%	35	%	35	%	35	%
Changes in computed taxes resulting from:
State income tax	4		5		5		4		5		5
Cost of removal	(1	)	(5	)	(5	)	(1	)	(5	)	(5	)
Renewable energy credits	(1	)	(1	)	—		—		—		—
Research and development credits	(1	)	—		—		(1	)	—		—
Other	—		—		(1	)	(1	)	—		(1	)
Effective tax rate	36	%	34	%	34	%	36	%	35	%	34	%

In 2016, Con Edison had a federal net operating loss of approximately $204 million, primarily due to bonus depreciation. Con Edison expects to carryback approximately $178 million of its 2016 net operating loss to 2007 and 2014, which will result in recovery of $32 million of income tax and reestablishment of $31 million of general business tax credits. The remaining 2016 federal net operating loss of $26 million will be carried forward to future years and will not expire until 2036. General business tax credits that were generated in 2016 ($207 million) and became available as a result of the net operating loss carryback ($31 million) will be carried forward to future years. Con Edison has $498 million in general business tax credit (primarily renewable energy tax credits), which if unused

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will begin to expire in 2032. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized.

Con Edison recorded a full valuation allowance of $3 million in 2015 against its charitable contribution carryforward from 2011. Due to the expiration of this charitable contribution carryforward in 2016, Con Edison wrote off the deferred tax asset and corresponding valuation allowance. Charitable contributions carryforward of $5 million and $6 million for 2015 and 2016, respectively, that will expire in 2020 and 2021, respectively, were recorded as a deferred tax asset and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized. In addition, a $12 million valuation allowance for New York City net operating loss carryforward and a $4 million valuation allowance for state net operating losses carryforward has been provided; as it is not more likely than not that the deferred tax asset will be realized.

In 2014, tax legislation was enacted in the State of New York that reduced the corporate franchise tax rate from 7.1 percent to 6.5 percent, beginning January 1, 2016. The application of this legislation decreased Con Edison’s accumulated deferred tax liabilities by $74 million ($69 million for CECONY), decreased Con Edison’s regulatory asset for future income tax by $11 million ($10 million for CECONY) and increased Con Edison’s regulatory liability by $62 million ($59 million for CECONY). The impact of this tax legislation on Con Edison’s effective tax rate was not material, and there was no impact on CECONY’s effective tax rate for the year ended December 31, 2014.

Under the Taxpayer Relief Act of 2012, 50 percent bonus depreciation expired on December 31, 2013. The Tax Increase Prevention Act of 2014 extended bonus depreciation for another year through December 31, 2014. As a result of the extension of bonus depreciation to 2014, Con Edison filed a refund request with the IRS in January 2015 to recover$224 million($128 millionfor CECONY) in estimated federal tax payments and received the refund in March 2015.

The Protecting Americans from Tax Hikes Act of 2015 extended bonus depreciation for property acquired and placed in service during 2015 through 2019. The bonus depreciation percentage is50 percentfor property placed in service during 2015, 2016 and 2017 and phases down to40 percentin 2018, and30 percentin 2019. As a result of the extension of bonus depreciation to 2015, Con Edison filed a refund request with the IRS in January 2016 to recover$160 millionin estimated federal tax payments. In February 2016, Con Edison received a refund of estimated taxes paid in the amount of $160 million ($143 million for CECONY).

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)	2016	2015	2014	2016	2015		2014
Balance at January 1,	$34	$34	$9	$2		$2		$—
Additions based on tax positions related to the current year	2	—	—	2	—		—
Additions based on tax positions of prior years	19	1	27	19	—		2
Reductions for tax positions of prior years	(13)	—	(2)	(2)	—		—
Reductions from expiration of statute of limitations	—	(1)	—	—	—		—
Settlements	—	—	—	—	—		—
Balance at December 31,	$42	$34	$34	$21	$2		$2

In 2016, Con Edison reached a settlement with New York State on two claims it had filed in previous years and reversed $11 million in uncertain tax positions. Of this amount, $8 million ($5 million, net of federal taxes) reduced Con Edison’s effective tax rate. The amount related to CECONY was $2 million ($1 million, net of federal taxes), all of which reduced CECONY’s effective tax rate. Current year additions of $21 million are for tax credits and prior years' claims filed in 2016.

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As of December 31, 2016, Con Edison reasonably expects to resolve within the next twelve months approximately $35 million ($24 million, net of federal taxes) of various federal and state uncertainties due to the expected completion of ongoing tax examinations, including $21 million ($14 million, net of federal taxes), which, if recognized, would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $17 million ($12 million, net of federal taxes), including $2 million, which, if recognized, would reduce CECONY’s effective tax rate.

The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In 2016, 2015 and 2014, the Companies recognized an immaterial amount of interest and no penalties for uncertain tax positions in their consolidated income statements. At December 31, 2016 and 2015, the Companies recognized an immaterial amount of interest and no penalties in their consolidated balance sheets.

At December 31, 2016, the total amount of unrecognized tax benefits that, if recognized, would reduce the Companies’ effective tax rate is $24 million ($17 million, net of federal taxes) with $3 million attributable to CECONY.

The federal tax returns for 2012 through 2015 remain open for examination. State income tax returns remain open for examination in New York for tax years 2006 through 2015 and in New Jersey for tax years 2008 through 2015.

Note M – 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 (authorized, but unissued) shares, treasury shares or shares purchased in the open market. The shares used during the year ended December 31, 2016 were new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2017.

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, 2016, 2015 and 2014:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Performance-based restricted stock	$42	$27	$22	$36	$23	$19
Time-based restricted stock	2	1	2	2	1	2
Non-employee director deferred stock compensation	2	2	2	2	2	2
Stock purchase plan	4	4	3	4	3	3
Total	$50	$34	$29	$44	$29	$26
Income tax benefit	$20	$14	$12	$18	$12	$10

Stock Options

The Companies last granted stock options in 2006. The stock options generally vested over a three-year period and had a term of 10 years. Options were granted at an exercise price equal to the fair market value of a common share when the option was granted. The Companies generally recognized compensation expense (based on the fair value of stock option awards) over the vesting period. No outstanding options remain as of December 31, 2016.

A summary of changes in the status of stock options as of December 31, 2016 is as follows:

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	Con Edison		CECONY
	Shares	Weighted Average Exercise Price	Shares	Weighted Average Exercise Price
Outstanding at December 31, 2015	79,125	$43.50	65,775	$43.50
Exercised	79,125	43.50	65,775	43.50
Forfeited	—	—	—	—
Outstanding at December 31, 2016	—	$—	—	$—

The following table summarizes information about stock options for the years ended December 31, 2016 and 2015:

	Con Edison			CECONY
(Millions of Dollars)	2016		2015	2016		2015
Aggregate intrinsic value (a)
Options outstanding		$—	$2		$—	$1
Options exercised	2		3	2		3
Cash received by Con Edison for payment of exercise price	3		6	3		5

(a) Aggregate intrinsic value represents the changes in the fair value of all outstanding options from their grant dates to December 31 of the years presented above.

The income tax benefit Con Edison realized from stock options exercised in the years ended December 31, 2016, 2015 and 2014 was $1 million.

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 represents 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:

	2016	2015	2014
Risk-free interest rate (a)	0.85% - 1.20%	0.64% - 3.28%	0.23% - 3.07%
Expected term (b)	3 years	3 years	3 years
Expected share price volatility (c)	17.72% - 18.22%	15.82%	13.14%

(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.

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A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2016 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, 2015	1,078,339	$45.26	$58.08	853,257	$45.37	$58.12
Granted	386,400	83.16	72.10	295,300	82.73	72.34
Vested	(351,230)	55.16	57.96	(285,162)	55.21	58.07
Forfeited	(26,372)	48.48	61.03	(15,053)	53.61	63.05
Non-vested at December 31, 2016	1,087,137	$55.45	$63.03	848,342	$54.92	$63.00

(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, 2016 is $34 million, including $27 million for CECONY, and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY.

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, 2016 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, 2015	64,980	$58.56	61,630	$58.55
Granted	23,000	76.62	21,800	76.62
Vested	(20,900)	61.03	(19,800)	61.03
Forfeited	(1,100)	60.13	(1,050)	60.43
Non-vested at December 31, 2016	65,980	$64.04	62,580	$64.03

The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2016 for Con Edison and CECONY was $2 million and is expected to be recognized over a weighted average period of one year.

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, 2016, approximately 27,600 units were issued at a weighted average grant date price of $74.37.

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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. 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 2016, 2015 and 2014, 720,268, 761,784 and 708,276 shares were purchased under the Stock Purchase Plan at a weighted average price of $72.67, $62.75 and $56.23 per share, respectively.

Note N – Financial Information by Business Segment

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

Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. Con Edison Transmission, which had begun investing in electric transmission and gas pipeline and storage assets (see Note U), was added in June 2016 as a separate reportable segment based on management’s reporting and decision-making, including performance evaluation and resource allocation. For comparison purposes, the previously reported financial information by business segments was reclassified to reflect the current business segment presentation.

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, 2016 (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	$8,106	$17		$865	$1,847	$2		$459	$495	$30,708	$1,819
Gas	1,508	6		159	357	(1)		105	92	7,553	811
Steam	551	88		82	58	(1)		39	30	2,595	126
Consolidation adjustments	—	(111)		—	—	—		—	—	—	—
Total CECONY	$10,165		$—	$1,106	$2,262		$—	$603	$617	$40,856	$2,756
O&R
Electric	$637		$—	$49	$95	$1		$24	$30	$1,949	$114
Gas	184	—		18	35	—		12	10	809	52
Other	—	—		—	—	—		—	—	—	—
Total O&R	$821		$—	$67	$130	$1		$36	$40	$2,758	$166
Clean Energy Businesses	$1,091	$7		$42	$183	$21		$34	$53	$2,551	$1,235
Con Edison Transmission	—	—		—	(3)	43		6	—	1,150	1,078
Other (b)	(2)	(7)		1	3	(1)		17	4	940	—
Total Con Edison	$12,075		$—	$1,216	$2,575	$64		$696	$714	$48,255	$5,235

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As of and for the Year Ended December 31, 2015 (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 (c)	Capital expenditures
CECONY
Electric	$8,172	$18		$820	$1,798	$(2)	$447	$447	$30,603	$1,658
Gas	1,527	6		142	356	(2)	96	100	6,974	671
Steam	629	86		78	93	(1)	41	41	2,653	106
Consolidation adjustments	—	(110)		—	—	—	—	—	—	—
Total CECONY	$10,328		$—	$1,040	$2,247	$(5)	$584	$588	$40,230	$2,435
O&R
Electric	$663		$—	$50	$103	$(2)	$23	$31	$2,140	$114
Gas	182	—		18	18	(2)	12	2	579	46
Other	—	—		—	—	—	—	—	—	—
Total O&R	$845		$—	$68	$121	$(4)	$35	$33	$2,719	$160
Clean Energy Businesses	$1,383	$(2)		$22	$58	$35	$11	$22	$1,680	$823
Con Edison Transmission	—	—		—	—	—	—	—	3	—
Other (b)	(2)	2		—	1	(2)	23	1	1,010	—
Total Con Edison	$12,554		$—	$1,130	$2,427	$24	$653	$644	$45,642	$3,418

As of and for the Year Ended December 31, 2014 (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 (c)	Capital expenditures
CECONY
Electric	$8,437	$16		$781	$1,712	$8	$412	$425	$30,295	$1,500
Gas	1,721	6		132	314	2	89	88	6,478	549
Steam	628	84		78	113	1	36	49	2,670	83
Consolidation adjustments	—	(106)		—	—	—	—	—	—	—
Total CECONY	$10,786		$—	$991	$2,139	$11	$537	$562	$39,443	$2,132
O&R
Electric	$680		$—	$46	$103	$3	$24	$29	$2,023	$105
Gas	212	—		15	25	—	10	6	786	37
Other	—	—		—	—	—	1	—	1	—
Total O&R	$892		$—	$61	$128	$3	$35	$35	$2,810	$142
Clean Energy Businesses	$1,244	$(10)		$19	$(60)	$28	$(8)	$(8)	$1,013	$447
Con Edison Transmission	—	—		—	—	—	—	—	1	—
Other (b)	(3)	10		—	2	—	27	—	804	—
Total Con Edison	$12,919		$—	$1,071	$2,209	$42	$591	$589	$44,071	$2,721

(a) For Con Edison, the income tax expense on non-operating income was $16 million, $40 million and $21 million in 2016, 2015 and 2014, respectively. For CECONY, the income tax expense on non-operating income was $14 million, $14 million and $7 million in 2016, 2015 and 2014, respectively.

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

(c) Reflects $237 million in 2014, related to the adoption of ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs” and ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes.” See Notes C and L.

Note O – Derivative Instruments and Hedging Activities

Commodity Derivatives

Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the consolidated balance sheet at fair value (see Note P), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules.

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The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at December 31, 2016 and 2015 were:

(Millions of Dollars)	2016				2015
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	$81	$(64)	$17	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	49	(43)	6		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$130	$(107)	$23		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(138)	$61	$(77)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(91)	52	(39)	(d)	(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(229)	$113	$(116)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(99)	$6	$(93)	(b)(d)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(45)	$7	(b)	$40	$(32)	$8	(b)
Noncurrent	41	(35)	6		48	(47)	1
Total fair value of derivative assets	$93	$(80)	$13		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(111)	$45	$(66)		$(121)	$71	$(50)
Noncurrent	(77)	44	(33)		(92)	56	(36)
Total fair value of derivative liabilities	$(188)	$89	$(99)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(95)	$9	$(86)	(b)	$(125)	$48	$(77)	(b)

(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, 2016 and 2015, margin deposits for Con Edison ($7 million and $26 million, respectively) and CECONY ($7 million and $26 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) Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet.

(d) Does not include ($1) million for interest rate swap (see below).

The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. 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 purchased power, gas purchased for resale and non-utility revenue in the reporting period in which they occur. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the years ended December 31, 2016 and 2015:

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		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016			2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$23		$1		$18			$2
Noncurrent	Deferred derivative gains	1		1		2			—
Total deferred gains/(losses)		$24		$2		$20			$2
Current	Deferred derivative losses	$22		$(16)		$18			$(11)
Current	Recoverable energy costs	(212)		(136)		(194)			(127)
Noncurrent	Deferred derivative losses	2		(25)		4			(23)
Total deferred gains/(losses)		$(188)		$(177)		$(172)			$(161)
Net deferred gains/(losses)		$(164)		$(175)		$(152)			$(159)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(101)	(a)	$(109)	(b)		$—			$—
	Gas purchased for resale	(112)		(106)		—			—
	Non-utility revenue	9	(a)	30	(b)	—			—
	Other operations and maintenance expense	1	(c)	(1)	(d)	1		(c)	(1)		(d)
Total pre-tax gain/(loss) recognized in income		$(203)		$(186)		$1			$(1)

(a) For the year ended December 31, 2016, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($5 million loss) and purchased power expense ($11 million gain).

(b) For the year ended December 31, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($1 million gain) and purchased power expense ($1 million loss).

(c) For the year ended December 31, 2016, Con Edison and CECONY recorded an unrealized gain in other operations and maintenance expense ($1 million).

(d) For the year ended December 31, 2015, Con Edison and CECONY recorded an unrealized loss in other operations and maintenance expense ($1 million).

The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at December 31, 2016:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	21,235,830	13,616	77,248,786	3,696,000
CECONY	19,258,400	7,500	71,060,000	3,696,000

(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, 2016, Con Edison and CECONY had $62 million and $20 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $25 million with commodity exchange brokers, $17 million with investment-grade counterparties, $11 million with non-investment grade/non-rated counterparties and $9 million with independent system operators. CECONY’s net credit exposure consisted of $14 million with commodity exchange brokers and $6 million with investment-grade counterparties.

The collateral requirements associated with, and settlement of, derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statement of cash flows. Most derivative instrument contracts contain provisions that may require a party to provide collateral on its derivative instruments that are in a

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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, 2016:

(Millions of Dollars)	Con Edison (a)	CECONY (a)
Aggregate fair value – net liabilities	$113	$103
Collateral posted	43	42
Additional collateral (b) (downgrade one level from current ratings)	11	10
Additional collateral (b)(c) (downgrade to below investment grade from current ratings)	75	65

(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 $43 million at December 31, 2016. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) Derivative instruments that are net assets have been excluded from the table. At December 31, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $15 million.

Interest Rate Swap

In December 2016, the Clean Energy Businesses acquired Coram Wind (see Note U) which holds an interest rate swap that terminates in June 2024, pursuant to which it pays a fixed-rate of 2.0855 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at the time of acquisition was a liability of $1 million which was added to Con Edison’s consolidated balance sheet. Subsequent changes to the fair value after the date of acquisition are recorded in the company’s consolidated income statement as other interest expense and were immaterial for the year ended December 31, 2016.

Note P – Fair Value Measurements

The accounting rules for fair value measurements and disclosures define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.

The accounting rules for fair value measurements and disclosures established a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows:

• Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange.

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• Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models.

• Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value.

Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2016 and 2015 are summarized below.

	2016						2015
(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)	$14	$33	$7		$(24)	$30	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	—	—		—	—	—	63	1		(63)	1
Other (a)(b)(d)	222	111	—		—	333	185	112	—		—	297
Total assets	$236	$144	$7		$(24)	$363	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$4	$144	$6		$(38)	$116	$16	$153	$1		$(65)	$105
Interest Rate Swap (a)(b)(c)(g)	—	1	—		—	1	—	—	—		—	—
Commodity held for sale (f)	—	—	—		—	—	1	133	7		(63)	78
Total liabilities	$4	$145	$6		$(38)	$117	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$10	$19	$1		$(10)	$20	$1	$9	$8		$17	$35
Other (a)(b)(d)	200	106	—		—	306	171	105	—		—	276
Total assets	$210	$125	$1		$(10)	$326	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$1	$124		$—	$(26)	$99	$14	$129		$—	$(57)	$86

(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. There were no transfers between levels 1, 2 and 3 for the years ended December 31, 2016 and 2015.

(b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, interest rate swap, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.

(c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2016 and 2015, 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) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet (see Note U).

(g) See Note O.

The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives. Under the Companies’

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policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives. Fair value and changes in fair value of commodity derivatives are reported on a monthly basis to the Companies’ risk committees, comprised of officers and employees of the Companies that oversee energy hedging at the Utilities and the Clean Energy Businesses. The risk management group reports to the Companies’ Vice President and Treasurer.

	Fair Value of Level 3 at December 31, 2016
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison — Commodity
Electricity	$(1)	Discounted Cash Flow	Forward energy prices (a)	$37.75-$55.00 per MWh
		Discounted Cash Flow	Forward capacity prices (a)	$2.42-$10.25 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	2	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
			Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(75.2)%-58.9%
			Inter-zonal forward price curves adjusted for historical zonal losses (b)	$1.11-$2.90 per MWh
Total Con Edison — Commodity	$1
CECONY — Commodity
Transmission Congestion Contracts	$1	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
			Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(75.2)%-58.9%

(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, 2016 and 2015 and classified as Level 3 in the fair value hierarchy:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of January 1,	$6	$20	$8	$13
Included in earnings	(7)	(20)	(1)	(6)
Included in regulatory assets and liabilities	(6)	1	(6)	—
Purchases	4	11	2	5
Sales (a)	4	—	—	—
Settlements	—	(6)	(2)	(4)
Ending balance as of December 31,	$1	$6	$1	$8

(a)Amounts represent derivative instruments novated as part of the assets of Con Edison Solutions’ retail electric supply business which were sold to a subsidiary of Exelon Corporation (see Note U).

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 (immaterial for both years) and purchased power costs ($6 million loss and $14 million loss) on the consolidated income statement for the years ended December 31, 2016 and 2015, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at December 31, 2016 and 2015 is included in non-utility revenues (immaterial for both years) and purchased power costs ($1 million loss and $8 million loss) on the consolidated income statement for the years ended December 31, 2016 and 2015, respectively.

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Note Q – 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.

Con Edison enters into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, Con Edison retains or may retain a variable interest in these entities.

CECONY

CECONY had a variable interest in a non-consolidated VIE, Astoria Energy, LLC (Astoria Energy), with which CECONY entered into a long-term electricity purchase agreement that expired in April 2016. CECONY has ongoing long-term electricity purchase agreements with the following two potential VIEs: Cogen Technologies Linden Venture, LP and Brooklyn Navy Yard Cogeneration Partners, LP. In 2016, requests were made of these counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY's maximum exposure to loss with respect to the potential VIEs.

Con Edison Development

Con Edison has a variable interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), which is a consolidated entity in which Con Edison Development has an 80 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project in Texas. Electricity generated by the project is sold to the City of San Antonio pursuant to a long-term power purchase agreement. At December 31, 2016 and 2015, Con Edison’s consolidated balance sheet includes $54 million and $58 million in net assets (as detailed in the table below) and the noncontrolling interest of the third party of $7 million and $9 million related to Texas Solar 4, respectively. Earnings for the year ended December 31, 2016 and 2015 were immaterial.

(Millions of Dollars)	2016	2015
Restricted cash	$8	$9
Receivable from parent company	35	32
Non-utility property, less accumulated depreciation of $9 and $5, respectively	104	107
Other assets	8	11
Total assets (a)	$155	$159
Long-term debt due within one year	$3	$2
Other liabilities	38	37
Long-term debt	60	62
Total liabilities (b)	$101	$101

(a) The assets of Texas Solar 4 represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE.

(b) The liabilities of Texas Solar 4 represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary.

The following table summarizes the VIEs in which Con Edison Development has entered into as of December 31, 2016:

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Project Name (a)	Generating Capacity (b) (MW AC)	Power Purchase Agreement Term in Years	Year of Initial Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (c)
Copper Mountain Solar 3	128	20	2014	Nevada	$179
Mesquite Solar 1	83	20	2013	Arizona	108
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	69
Broken Bow II	38	25	2014	Nebraska	48
Texas Solar 4	32	25	2014	Texas	47

(a) With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. With the exception of Texas Solar 4, Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development.

(b) Represents Con Edison Development’s ownership interest in the project.

(c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet. For consolidated investments, such as Texas Solar 4, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest ($7 million for Texas Solar 4). Con Edison did not provide any financial or other support during the year that was not previously contractually required.

Note R – 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.

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.

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At December 31, 2016, the liabilities for asset retirement obligations of Con Edison and CECONY were $246 million and $227 million, respectively. At December 31, 2015, the liabilities for asset retirement obligations of Con Edison and CECONY were $242 million and $234 million, respectively. The change in liabilities at December 31, 2016 was due to changes in estimated cash flows of $29 million and $19 million for Con Edison and CECONY, respectively, and accretion expense of $10 million and $9 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $35 million for both Con Edison and CECONY. Con Edison and CECONY also recorded reductions of $37 million and $23 million during the years ended December 31, 2016 and 2015, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.

Note S – Related Party Transactions

The Utilities and the Clean Energy Businesses provide administrative and other services to each other pursuant to cost allocation procedures approved by the NYSPSC. The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2016, 2015 and 2014 were as follows:

	CECONY
(Millions of Dollars)	2016	2015	2014
Cost of services provided	$108	$99	$90
Cost of services received	64	60	57

In addition, CECONY and O&R have joint gas supply arrangements, in connection with which CECONY sold to O&R $47 million, $54 million and $80 million of natural gas for the years ended December 31, 2016, 2015 and 2014, 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 year ended December 31, 2016, the amounts billed by the Utilities to NY Transco were immaterial. In May 2016, CECONY transferred certain electric transmission projects to NY Transco (see Note U).

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) (see Note U). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. From the inception of the joint venture in June 2016 through December 31, 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $18 million. In addition, the Clean Energy Businesses entered into two electricity sales agreements with Stagecoach under which the amounts received in 2016 were immaterial.

CECONY has a financial electric capacity contract with Con Edison Energy for the period May 2016 through April 2017. For the year ended December 31, 2016, Con Edison Energy's realized gains under this contract were immaterial.

FERC has authorized CECONY through 2017 to lend funds to O&R from time to time, for periods of not more than 12 months, in amounts not to exceed $250 million outstanding at any time, at prevailing market rates. There were no outstanding loans to O&R at December 31, 2016 and 2015.

Note T – New Financial Accounting Standards

In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board jointly issued a revenue recognition standard that will supersede the revenue recognition requirements within Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. Amendments were issued subsequently to clarify key areas including principal/agent considerations, performance obligations, licensing, sales taxes, noncash consideration, and contracts. The new standard is effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for reporting periods beginning after

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December 15, 2016, however, the Companies plan to adopt the new standard for reporting periods beginning after December 15, 2017.

Under the new standard, companies may use either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a modified retrospective approach with the cumulative effect of initially adopting ASU 2014-09 recognized at the date of adoption (which includes additional footnote disclosures). The Companies anticipate using the modified retrospective approach.

The Companies are currently in the process of evaluating the impact of the new standard on their various revenue streams. The majority of the Companies’ sales are derived from tariffs to provide electric, gas, and steam service to customers. For such tariffs, the Companies expect that the revenue from contracts with the customer under ASU 2014-09 will be equivalent to the electricity, gas, or steam supplied in that period which is consistent with current practice. Consequently, the Companies do not anticipate that the new standard will significantly impact the amount and/or timing of such revenues. The Companies continue to review the potential impacts of other revenue at the Utilities and the Clean Energy Businesses on the Companies' financial position, results of operations and liquidity as well as the additional disclosures required under the new standard.

In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. Based on the existing portfolio of leases at implementation, for leases currently classified as operating leases, the Companies expect to recognize on the statements of financial position right-of-use assets and lease liabilities. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ results of operations and liquidity.

In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

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In March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” The amendments require that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning after December 15, 2016. The company elected to early adopt this standard as permitted, and it did not have a material impact on the Companies’ financial position, results of operations and liquidity.

In May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of ASU 2014-09 and 2014-16. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In August 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force).” The amendment specifies the classification and presentation of certain cash flow items to reduce diversity in practice. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In October 2016, the FASB issued amendments to the guidance for Income Taxes through ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory).” The amendment clarifies the tax treatment of intra-entity transfers of assets other than inventory. The updated guidance requires entities to recognize the income tax consequences of an intra-entity transfer of assets other than inventory when the transfer occurs. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In October 2016, the FASB issued amendments to the guidance for Consolidation through ASU 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control.” The amendments in this update change how a single decision maker of a VIE will consider its indirect interests in a VIE held by related parties under common control when performing the primary beneficiary analysis. If a single decision maker and its related parties are under common control, the single decision maker must evaluate indirect interests

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on a proportionate basis when evaluating whether it is a primary beneficiary of the VIE. The guidance does not change the characteristics of a primary beneficiary under GAAP but has amended the considerations in the evaluation of determining the primary beneficiary of a VIE under common control. For public entities, the amendments are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In November 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-18, “Update 2016-18-Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force).” The amendments in this update clarify the presentation of changes in restricted cash and restricted cash equivalents in the statement of cash flows. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In January 2017, the FASB issued amendments to the guidance for Business Combinations through ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business.” The amendments in this update clarify the definition of a business and provide guidance on evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In January 2017, the FASB issued amendments to the guidance for the subsequent measurement of goodwill through ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The amendments in this update simplify goodwill impairment testing by eliminating Step 2 of the goodwill impairment test wherein an entity has to compute the implied fair value of goodwill by performing procedures to determine the fair value of its assets and liabilities. Under the new guidance, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value up to the total amount of goodwill allocated to that reporting unit. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

Note U – Acquisitions, Investments and Dispositions

Acquisitions and Investments

Texas Solar 7

In January 2016, Con Edison Development acquired a 100 percent equity interest in a company that is the owner of a 106 MW (AC) solar electric production project in Texas (Texas Solar 7) for $227 million, as to which $218 million was recorded as non-utility construction work in progress and the remaining $9 million was recorded as other receivables. At December 31, 2016 net assets of the project were approximately $127 million, inclusive of $41 million in an intangible asset recorded as an adjustment to the purchase price allocation in December 2016. The intangible asset pertains to the value of the project's power purchase agreement, relative to current market rates, and is being amortized over the life of the agreement. The project has been financed, in part, by debt secured by the project. Electricity generated by this project is to be purchased by the City of San Antonio pursuant to a long-term power purchase agreement. The project commenced commercial operation in the third quarter of 2016. Con Edison's equity interest in Texas Solar 7 is consolidated in the financial statements.

Mountain Valley Pipeline

In January 2016, CET Gas acquired a 12.5 percent equity interest in Mountain Valley Pipeline, LLC (MVP), a company developing a proposed gas transmission project in West Virginia and Virginia. The company's initial contribution to MVP was $18 million. At December 31, 2016, CET Gas' investment in MVP was $48 million. The estimated total project cost is $3,000 million to $3,500 million. Subject to FERC approval, MVP is targeting to be fully in-service during 2018. Con Edison is accounting for its equity interest in MVP as an equity method investment.

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NY Transco

In January 2016, CECONY entered into an agreement to transfer certain electric transmission projects to NY Transco, a company in which CET Electric has a 45.7 percent equity interest. In April 2016, the NYSPSC authorized CECONY, subject to certain conditions, to transfer the projects to NY Transco. In May 2016, CECONY transferred the projects to NY Transco for a purchase price of $122 million and an $8 million payment for easement rights on certain associated property. At December 31, 2016, CET Electric's investment in NY Transco was $51 million. Con Edison is accounting for its equity interest in NY Transco as an equity method investment.

Stagecoach Gas Services

In April 2016, a CET Gas subsidiary agreed with a subsidiary of Crestwood to form a joint venture to own, operate and further develop existing gas pipeline and storage businesses located in northern Pennsylvania and southern New York. The transaction was substantially completed in June 2016, and the remainder was completed in November 2016. Crestwood contributed businesses to a new entity, Stagecoach, and the CET Gas subsidiary purchased a 50 percent equity interest in Stagecoach for $974 million. At December 31, 2016, CET Gas' investment in Stagecoach was $992 million. Con Edison is accounting for its equity interest in Stagecoach as an equity method investment.

Pilesgrove

In June 2016, Con Edison Development recorded an $8 million ($5 million, net of taxes) impairment charge on its 50 percent equity interest in Pilesgrove Solar, LLC (Pilesgrove), which owns an 18 MW (AC) solar electric production project in New Jersey. In August 2016, Con Edison Development acquired the remaining 50 percent equity interest in Pilesgrove for a purchase price of approximately $16 million and recorded a bargain purchase gain of $8 million ($5 million, net of taxes); $45 million was recorded as non-utility property and the remaining $3 million was recorded as current assets. The impairment charge and bargain purchase gain are included in Investment and other income on Con Edison’s consolidated income statement. Con Edison's equity interest in Pilesgrove is consolidated in the financial statements. At December 31, 2016, net assets of the project were approximately $45 million.

Panoche Valley

In October 2016, Con Edison Development, which owned a 50 percent equity interest, acquired the remaining 50 percent equity interest in Panoche Holdings, LLC (Panoche), which is developing a 240 MW (AC) solar electric production project in California, for cash consideration of $28 million and the release of Panoche from its obligation under a $242 million note payable to Con Edison Development. At the time of acquisition, $290 million was recorded as non-utility construction work in process, $22 million was recorded as other assets and $14 million was recorded as current liabilities. The amounts recorded are subject to adjustments to the preliminary purchase price allocation. Con Edison's equity interest in Panoche is consolidated in the financial statements. At December 31, 2016, net assets of the project were approximately $388 million.

Coram Wind

In December 2016, Con Edison Development acquired a 100 percent equity interest in Coram California Development, LP (Coram), which owns a 102 MW (AC) wind electric production project in California for $97 million, as to which $191 million was recorded as non-utility property, $78 million was recorded as an intangible asset, $8 million of restricted cash was recorded as other current assets, and $180 million was recorded as long term debt. The intangible asset pertains to the value of the project's power purchase agreement, relative to current market rates, and is being amortized over the life of the agreement. The amounts recorded are subject to adjustments to the preliminary purchase price allocation. The project commenced commercial operation in March 2012. Con Edison's equity interest in Coram is consolidated in the financial statements. At December 31, 2016, net assets of the project were approximately $96 million.

Dispositions

Pike County Light & Power Company (Pike)

In October 2015, O&R entered into an agreement to sell Pike to Corning Natural Gas Holding Corporation (Corning). In August 2016, the sale was completed. O&R received cash consideration of $15 million for the sale. O&R has agreed to provide transition services to Corning for operations and customer support for a period of up to 18 months subsequent to the sale. In addition, O&R will continue to purchase and sell to Pike electric and gas commodity for three years. Pike has an option to extend the service for up to an additional three years. At September 30, 2015, O&R recorded an impairment charge of $5 million ($3 million, net of taxes), representing the difference between the carrying amount of Pike’s assets and the estimated sales proceeds. At December 31, 2015,

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Pike’s total assets and liabilities held for sale were $23 million and $5 million, respectively. There were no amounts outstanding at December 31, 2016.

Con Edison Solutions' Retail Electric Supply Business

In July 2016, Con Edison Solutions entered into an agreement to sell the assets of its retail electric supply business (including retail contracts, related derivative instruments, information systems, and accounts receivable) to a subsidiary of Exelon Corporation (Exelon). In September 2016, the sale was completed for cash consideration of $235 million, subject to working capital adjustments. The sale resulted in a gain of $104 million ($56 million, net of taxes), inclusive of a $65 million ($42 million, net of taxes) gain on derivative instruments. The tax effect of the sale includes $16 million ($10 million, net of federal tax) of state taxes related to a change in the apportionment of state income taxes. Con Edison Solutions has agreed to provide transition services to the Exelon subsidiary for operations and customer support through the end of 2017 during which period certain guarantees or other credit support provided by Con Edison in connection with the retail electric supply business may continue in effect. See Note H. At December 31, 2015, Con Edison Solutions' total assets and liabilities held for sale were $134 million and $84 million, respectively. There were no amounts outstanding at December 31, 2016.

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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)	2016	2015	2014
Equity in earnings of subsidiaries	$1,254	$1,195	$1,101
Other income (deductions), net of taxes	32	27	19
Interest expense	(41)	(29)	(28)
Net Income	$1,245	$1,193	$1,092
Comprehensive Income	$1,252	$1,204	$1,072
Net Income Per Share – Basic	$4.15	$4.07	$3.73
Net Income Per Share – Diluted	$4.12	$4.05	$3.71
Dividends Declared Per Share	$2.68	$2.60	$2.52
Average Number Of Shares Outstanding—Basic (In Millions)	300.4	293.0	292.9
Average Number Of Shares Outstanding—Diluted (In Millions)	301.9	294.4	294.0

(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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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)	2016	2015	2014
Net Income	$1,245	$1,193	$1,092
Equity in earnings of subsidiaries	(1,254)	(1,195)	(1,101)
Dividends received from:
CECONY	744	872	712
O&R	43	81	40
Clean Energy Businesses	10	8	8
Change in Assets:
Special deposits	—	—	314
Income taxes receivable	87	58	(224)
Other – net	(152)	(382)	(199)
Net Cash Flows from Operating Activities	723	635	642
Investing Activities
Contributions to subsidiaries	(691)	(15)	(1)
Long term debt receivable from affiliated companies	(900)	—	—
Net Cash Flows Used in Investing Activities	(1,591)	(15)	(1)
Financing Activities
Net proceeds of short-term debt	(53)	162	101
Issuance of long-term debt	900	—	—
Retirement of long-term debt	(2)	(2)	(2)
Debt issuance costs	(5)	—	—
Issuance of common shares for stock plans, net of repurchases	51	1	(10)
Issuance of common shares - public offering	702	—	—
Common stock dividends	(763)	(733)	(739)
Net Cash Flows Used in Financing Activities	830	(572)	(650)
Net Change for the Period	(38)	48	(9)
Balance at Beginning of Period	51	3	12
Balance at End of Period	$13	$51	$3

(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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Condensed Financial Information of Consolidated Edison, Inc. (a)

Condensed Balance Sheet

(Parent Company Only)

	December 31,
(Millions of Dollars)	2016	2015
Assets
Current Assets
Cash and temporary cash investments	$13	$51
Special deposits	1	1
Accounts receivable – other	—	4
Income taxes receivable	79	166
Accounts receivable from affiliated companies	702	517
Prepayments	24	34
Other current assets	18	17
Total Current Assets	837	790
Investments in subsidiaries	13,991	12,737
Goodwill	406	406
Deferred income tax	42	11
Long term debt receivable from affiliated companies	900	—
Other noncurrent assets (b)	16	7
Total Assets	$16,192	$13,951
Liabilities and Shareholders’ Equity
Current Liabilities
Long-term debt due within one year	$2	$2
Notes payable	384	437
Accounts Payable	1	—
Accounts payable to affiliated companies	288	146
Accrued taxes	7	—
Other current liabilities	14	10
Total Current Liabilities	696	595
Total Liabilities	696	595
Long-term debt (b)	1,198	304
Shareholders’ Equity
Common stock, including additional paid-in capital	5,887	5,062
Retained earnings	8,411	7,990
Total Shareholders’ Equity	14,298	13,052
Total Liabilities and Shareholders’ Equity	$16,192	$13,951

(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

For the Years Ended December 31, 2016, 2015 and 2014

				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):
		2016	$96	$63		$—	$76	$83
		2015	$106	$77	—		$87	$96
		2014	$103	$98	—		$95	$106
CECONY	Allowance for uncollectible accounts (a):
		2016	$91	$57		$—	$70	$78
		2015	$98	$69	—		$76	$91
		2014	$95	$91	—		$88	$98

(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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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.

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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 15, 2017. The proxy statement is to be filed pursuant to Regulation 14A not later than 120 days after December 31, 2016, 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, 2016 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)	334,465		—	—
2013 LTIP (b)	1,313,462		—	3,686,073
Stock Purchase Plan (c)	—		—	8,066,054
Total equity compensation plans approved by security holders	1,647,927		—	11,752,127
Total equity compensation plans not approved by security holders	3,500	(d)	—	—
Total	1,651,427		—	11,752,127

(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: (A) 211,977 shares for stock unit awards made prior to 2013 that have vested and for which the receipt of shares was deferred and (B) 122,488 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. 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 (1,122,111 shares for performance restricted stock units and 65,980 shares for time-based restricted stock units); (B) 125,371 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 M 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.”

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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).

In accordance with General Instruction G(3) to Form 10-K, other information regarding CECONY’s Executive Officers may be found in Part I of this report under the caption “Executive Officers of the Registrant.”

Fees paid or payable by CECONY to its principal accountant, PricewaterhouseCoopers LLP, for services related to 2016 and 2015 are as follows:

	2016	2015
Audit fees	$3,576,897	$3,423,777
Audit-related fees (a)	516,786	8,215
Tax fees (b)	25,000	75,088
All other fees (c)	—	102,867
Total fees	$4,118,683	$3,609,947

(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 2016 and 2015 are fees related to other accounting and professional services.

(b) Relates to fees for tax compliance reporting relating to the Foreign Account Tax Compliance Act.

(c) Relates to fees in 2015 for cybersecurity risk review.

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.

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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.

Con Edison

3.1.1	Restated Certificate of Incorporation of Consolidated Edison, Inc. (Con Edison). (Designated in the Registration Statement on Form S-4 of Con Edison (No. 333-39165) as Exhibit 3.1)
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)
4.1.1.1	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 the Registration Statement on Form S-3 of Con Edison (No. 333-102005) as Exhibit 4.1)
4.1.1.2	Form of CEI’s 2.00% Debentures, Series 2016 A. (Designated in CEI’s Current Report on Form 8-K, dated May 10, 2016 (File No. 1-14514) as Exhibit 4)
4.1.2	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)
4.1.3	$400 million Credit Agreement dated as of June 10, 2016 among CEI, as Borrower, the Lenders party thereto and Mizuho Bank, Ltd., as Administrative Agent and as Lead Arranger and Bookrunner. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2016 (File No. 1-14514) as Exhibit 4.1.2)
10.1.1	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)
10.1.2.1	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. (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)
10.1.3.1	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.
10.1.4	The Consolidated Edison Retirement Plan. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2014 (File No. 1-14514) as Exhibit 10.1.4)
10.1.5.1	The Consolidated Edison Thrift Plan. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2014 (File No. 1-14514) as Exhibit 10.1.5)
10.1.5.2	Amendment, dated June 13, 2016, to the Consolidated Edison Thrift Savings Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the year quarterly period ended June 30, 2016 (File No. 1-14514) as Exhibit 10.1)
10.1.6.1	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 10.1.8.10)
10.1.6.2	Form of Restricted Stock Unit Award under the Con Edison Long Term Incentive Plan. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2008 (File No. 1-14514) as Exhibit 10.1.7.2)
10.1.6.3	Form of Restricted Stock Unit Award for Officers under the Con Edison Long Term Incentive Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the year quarterly period ended March 31, 2011 (File No. 1-14514) as Exhibit 10.1)

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10.1.6.4	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)
10.1.6.5	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)
10.1.6.6	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)
10.1.7.1	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)
10.1.7.2	Form of Performance Unit Award for Officers under the Consolidated Edison, Inc. Long Term Incentive Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2013 (File No. 1-14514) as Exhibit 10.1.2)
10.1.7.3	Form of Performance Unit Award for Certain Specified Officers under the Consolidated Edison, Inc. Long Term Incentive Plan. (Designated in Con Edison’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2014 (File No. 1-14514) as Exhibit 10.1)
10.1.7.4	Amendment No. 1 to the Consolidated Edison, Inc. Long Term Incentive Plan.
10.1.7.5	Amendment No. 2 to the Consolidated Edison, Inc. Long Term Incentive Plan.
10.1.8	Description of Directors’ Compensation, effective as of December 31, 2016
10.1.9	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)
10.1.10	Employment offer letter, dated November 21, 2013 to John McAvoy. (Designated in Con Edison’s Current Report on Form 8-K, dated November 21, 2013 (File No. 1-14514) as Exhibit 10)
10.1.11	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 CEI’s Current Report on Form 8-K, dated April 20, 2016 (File No. 1-14514) as Exhibit 10)
12.1	Statement of computation of Con Edison’s ratio of earnings to fixed charges for the years 2012 – 2016
21.1	Subsidiaries of Con Edison. (Designated in Con Edison’s Annual Report on Form 10-K for the year ended December 31, 2003 (File No. 1-14514) as Exhibit 21.1)
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

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.

160

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 the Annual Report on Form 10-K of CECONY for the year ended December 31, 1989 (File No. 1-1217) as Exhibit 3(a))
3.2.1.2	The following certificates of amendment of Restated Certificate of Incorporation of CECONY filed with the Department of State of the State of New York, which are designated as follows:

	Securities Exchange Act File No. 1-1217
Date Filed With Department of State	Form	Date	Exhibit
5/16/1988	10-K	12/31/1989	3	(b)
6/2/1989	10-K	12/31/1989	3	(c)
4/28/1992	8-K	4/24/1992	4	(d)
8/21/1992	8-K	8/20/1992	4	(e)
2/18/1998	10-K	12/31/1997	3.1.2.3

3.2.2	By-laws of CECONY, effective May 18, 2015. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2015 (File No. 1-1217) as Exhibit 3.2)
4.2.1	Participation Agreement, dated as of July 1, 1999, between New York State Energy Research and Development Authority (NYSERDA) and CECONY. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 1999 (File No. 1-1217) as Exhibit 4.1)
4.2.2	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)
4.2.3	Participation Agreement, dated as of November 1, 2001, between NYSERDA and CECONY. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2001 (File No. 1-1217) as Exhibit 10.2.1)
4.2.4	Participation Agreement, dated as of January 1, 2004, between NYSERDA and CECONY. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2003 (File No. 1-1217) as Exhibit 4.2.6)
4.2.5	Participation Agreement, dated as of January 1, 2004, between NYSERDA and CECONY. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2003 (File No. 1-1217) as Exhibit 4.2.7)
4.2.6	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)
4.2.7	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)
4.2.8.1	Indenture of Trust, dated as of July 1, 1999 between NYSERDA and HSBC Bank USA, as trustee. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 1999 (File No. 1-1217) as Exhibit 4.2)
4.2.8.2	Supplemental Indenture of Trust, dated as of July 1, 2001, to Indenture of Trust, dated July 1, 1999 between NYSERDA and HSBC Bank USA, as trustee. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2001 (File No. 1-1217) as Exhibit 10.2.2)
4.2.9.1	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)
4.2.9.2	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)
4.2.10	Indenture of Trust, dated as of November 1, 2001, between NYSERDA and The Bank of New York, as trustee. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2001 (File No. 1-1217) as Exhibit 10.2.2)
4.2.11	Indenture of Trust, dated as of January 1, 2004, between NYSERDA and The Bank of New York. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2003 (File No. 1-1217) as Exhibit 4.2.12)

161

4.2.12	Indenture of Trust, dated as of January 1, 2004, between NYSERDA and The Bank of New York. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2003 (File No. 1-1217) as Exhibit 4.2.13)
4.2.13	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)
4.2.14.1	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)
4.2.14.2	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)
4.2.15.1	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, 1990 (File No. 1-1217) as Exhibit 4(h))
4.2.15.2	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, 1995 (File No. 1-1217) as Exhibit 4.13)
4.2.15.3	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)

4.2.16 The following forms of CECONY’s Debentures:

			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
5.85	%	Series 2008 A	8-K	4/4/2008	4.1
6.75	%	Series 2008 B	8-K	4/4/2008	4.2
7.125	%	Series 2008 C	8-K	12/4/2008	4
6.65	%	Series 2009 B	8-K	3/25/2009	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 2016A	8-K	6/14/2016	4
2.90	%	Series 2016B	8-K	11/10/2016	4.1
4.30	%	Series 2016C	8-K	11/10/2016	4.2

10.2.1	Amended and Restated Agreement and Settlement, dated September 19, 1997, between CECONY and the Staff of the New York State Public Service Commission (without Appendices). (Designated in CECONY’s Current Report on Form 8-K, dated September 23, 1997 (File No. 1-1217) as Exhibit 10)
10.2.2	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)
10.2.3.1	Planning and Supply Agreement, dated March 10, 1989, between CECONY and the Power Authority of the State of New York. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 1992 (File No. 1-1217) as Exhibit 10(gg))

162

10.2.3.2	Delivery Service Agreement, dated March 10, 1989, between CECONY and the Power Authority of the State of New York. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 1992 (File No. 1-1217) as Exhibit 10(hh))
10.2.4	Agreement and Plan of Exchange, entered into on October 28, 1997, between Con Edison and CECONY. (Designated in the Registration Statement on Form S-4 of Con Edison (No. 333-39165) as Exhibit 2)
10.2.5	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)
10.2.6.1	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)
10.2.6.2	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)
10.2.6.3	Amendment One to the Consolidated Edison Company of New York, Inc. Supplemental Retirement Income Plan.
10.2.7.1	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)
10.2.7.2	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)
10.2.8	Supplemental Medical Plan for the Benefit of CECONY’s officers. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 1991 (File No. 1-1217) as Exhibit 10(aa))
10.2.9	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.
10.2.10.1	The Consolidated Edison Company of New York, Inc. Deferred Income 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 10.2.10)
10.2.10.2	Amendment, executed December 19, 2013, to The Consolidated Edison Company of New York, Inc. Deferred Income Plan. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2013 (File No. 1-1217) as Exhibit 10.2.10.2)
10.2.10.3	Amendment One to the Consolidated Edison Company of New York, Inc. Deferred Income Plan
10.2.11.1	The Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan, effective as of January 1, 2005, as amended effective 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 10.2.11)
10.2.11.2	Amendment, dated October 21, 2009, to The Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2009 (File No. 1-1217) as Exhibit 10.2.1)
10.2.11.3	Amendment Number 2, dated December 17, 2010, to The Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-1217) as Exhibit 10.2.11.3)
10.2.11.4	Amendment Number 3, dated December 21, 2011, to The Consolidated Edison Company of New York, Inc. 2005 Executive Incentive Plan. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-1217) as Exhibit 10.2.11.4)
10.2.11.5	Amendment Number 4 to the 2005 Executive Incentive Plan. (Designated in CECONY’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2012 (File No. 1-1217) as Exhibit 10.2)
10.2.11.6	Amendment Number 5 to the 2005 Executive Incentive Plan. (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2013 (File No. 1-1217) as Exhibit 10.2.11.6)
10.2.11.7	Amendment Number 6 to the 2005 Executive Incentive Plan (Designated in CECONY’s Annual Report on Form 10-K for the year ended December 31, 2015 (File No. 1-1217) as Exhibit 10.2.11.7)
10.2.12.1	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)
10.2.12.2	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)
10.2.13	Employment Agreement, dated February 18, 1999, between CECONY and Frances Resheske. (Designated in CECONY’s Annual Report on Form 10-K, for the year ended December 31, 2006 (File No. 1-1217) as Exhibit 10.2.14)
12.2	Statement of computation of CECONY’s ratio of earnings to fixed charges for the years 2012 – 2016
23.2	Consent of PricewaterhouseCoopers LLP
31.2.1	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer

163

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

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.

164

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 16, 2017.

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 16, 2017.

Signature	Registrant	Title
/s/ John McAvoy	Con Edison	Chairman of the Board, President, Chief Executive Officer and Director (Principal Executive Officer)
John McAvoy	CECONY	Chairman of the Board, 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/ Robert Muccilo	Con Edison	Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)
Robert Muccilo	CECONY	Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer)
/s/ Vincent A. Calarco	Con Edison CECONY	Director Trustee
Vincent A. Calarco
/s/ George Campbell Jr.	Con Edison CECONY	Director Trustee
George Campbell Jr.
/s/ Michael J. Del Giudice	Con Edison CECONY	Director Trustee
Michael J. Del Giudice
/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/ 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/ L. Frederick Sutherland	Con Edison CECONY	Director Trustee
L. Frederick Sutherland

165

EX-10.1.3.2

Exhibit 10.1.3.2

AMENDMENT ONE

TO

THE CONSOLIDATED EDISON, INC.

STOCK PURCHASE PLAN

(As Amended and Restated Effective May 19, 2014)

In accordance with resolutions adopted by the Board of Directors of Consolidated Edison Transmission, Inc., (“CET”) on November 4, 2016 and the Board of Directors of Consolidated Edison, Inc. and the Board of Trustees of Consolidated Edison Company of New York, Inc. on November 17, 2016, approving CET’s adoption of the Consolidated Edison, Inc. Stock Purchase Plan (the “Plan”), the undersigned hereby approves, effective as of January 1, 2017, the amendment to the Plan set forth below.

APPENDIX B (PARTICIPATING EMPLOYERS) is amended by adding the following section:

(e) Consolidated Edison Transmission, Inc. shall become a Participating Employer in the Plan effective as of January 1, 2017, and its eligible employees shall be subject to the same terms and conditions as other eligible employees of the Plan.

IN WITNESS WHEREOF, the undersigned has executed this instrument this 22 day of December, 2016.

/s/ Richard Bagwell

Plan Administrator, and Vice President -

Human Resources

Consolidated Edison Company of New York, Inc.

EX-10.1.7.4

Exhibit 10.1.7.4

AMENDMENT NO. 1

CONSOLIDATED EDISON, INC.

LONG TERM INCENTIVE PLAN

Effective April 1, 2014

Pursuant to the resolutions adopted by the Board of Directors of Consolidated Edison, Inc., at a meeting duly held on February 20, 2014, the undersigned hereby ratifies effective as of April 1, 2014, the amendment set forth below to the Consolidated Edison, Inc. Long Term Incentive Plan (effective May 20, 2013).

ARTICLE 7. DIRECTOR PARTICIPANTS is amended as follows:

1. Subsection (a) of Section 7.2 Award of Stock Units is amended by adding a new subsection (i) as follows:

(i) Effective April 1, 2014, if a Director is a member of the Board on the date of an Annual Meeting, on the first business day after each such Annual Meeting, he or she will be granted an annual Award of Stock Units with a Fair Market Value of $120,000. The amount determined will be rounded (either up or down) to the nearest whole Stock Unit. The maximum number of Shares that may be subject to Awards granted in any calendar year to a Director is 10,000 Shares, subject to adjustment as provided in Section 6.4.

IN WITNESS WHEREOF, the undersigned has executed this instrument this 22 day of December, 2016.

/s/ Richard Bagwell

Plan Administrator, Consolidated Edison, Inc.

Long Term Incentive Plan and

Vice President - Human Resources

Consolidated Edison Company of New York, Inc.

EX-10.1.7.5

Exhibit 10.1.7.5

AMENDMENT NO. 2

CONSOLIDATED EDISON, INC.

LONG TERM INCENTIVE PLAN

Effective April 1, 2016

Pursuant to the resolutions adopted by the Board of Directors of Consolidated Edison, Inc., at a meeting duly held on February 18, 2016, the undersigned hereby approves, effective as of April 1, 2016, the amendment set forth below to the Consolidated Edison, Inc. Long Term Incentive Plan (effective May 20, 2013).

ARTICLE 7. DIRECTOR PARTICIPANTS is amended as follows:

1. Subsection (a) of Section 7.2 Award of Stock Units is amended by adding a new subsection (ii) as follows:

(ii) Effective April 1, 2016, if a Director is a member of the Board on the date of an Annual Meeting, on the first business day after each such Annual Meeting, he or she will be granted an annual Award of Stock Units with a Fair Market Value of $135,000. The amount determined will be rounded (either up or down) to the nearest whole Stock Unit. The maximum number of Shares that may be subject to Awards granted in any calendar year to a Director is 10,000 Shares, subject to adjustment as provided in Section 6.4.

IN WITNESS WHEREOF, the undersigned has executed this instrument this 22 day of December, 2016.

/s/ Richard Bagwell

Plan Administrator, Consolidated Edison, Inc.

Long Term Incentive Plan and

Vice President - Human Resources

Consolidated Edison Company of New York, Inc.

EX-10.1.8

Exhibit 10.1.8

Description of Directors’ Compensation

The following tables show, effective as of December 31, 2016, 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(1)	$100,000
Lead Director Retainer	$35,000
Chair of Audit Committee Retainer	$25,000
Member of Audit Committee Retainer (excluding the Audit Committee Chair)	$10,000
Chair of Corporate Governance and Nominating Committee Retainer	$10,000
Chair of Management Development and Compensation Committee Retainer	$15,000
Retainer for Chairs of: Environment, Health and Safety Committee; Finance Committee; and Operations Oversight Committee	$5,000
Acting Committee Chair Fee (where the regular Chair is absent)	$200
Audit Committee member fee (for each meeting of the Audit Committee attended)	$2,000
Committee member fee (for each Committee meeting attended)	$1,500
Annual equity award (deferred stock units) (2)	$135,000

Footnote:

(1) Effective April 1, 2016, the annual retainer was increased from $90,000 to $100,000.

(2) Effective April 1, 2016, the annual equity award was increased from $120,000 to $135,000.

Non-employee Directors participate in the Company’s Long Term Incentive Plan (the “LTIP”). Pursuant to the LTIP, each non-employee Director is allocated an annual equity award of $135,000 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 pro rated. 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 prior annual equity award of stock units, in accordance with the terms of the LTIP and Section 409A of the Internal Revenue Code. Each non-employee Director may also elect to defer all or a portion of his or her retainers and meeting fees 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. 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, the annual stock unit awards, and the 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, meeting fees, or annual equity award 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”).

Exhibit 10.1.8

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-12.1

Exhibit 12.1

Consolidated Edison, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Years Ended December 31,
	2016	2015	2014	2013	2012
Earnings
Net Income	$1,245	$1,193	$1,092	$1,062	$1,141
Preferred Stock Dividend	—	—	—	—	3
(Income) or Loss from Equity Investees	(28)	(34)	(27)	(6)	(4)
Minority Interest Loss	—	—	—	—	—
Income Tax	698	605	568	476	600
Pre-Tax Income	$1,915	$1,764	$1,633	$1,532	$1,740
Add: Fixed Charges*	730	701	636	764	638
Add: Distributed Income of Equity Investees	—	—	—	—	—
Subtract: Interest Capitalized	—	—	—	—	—
Subtract: Pre-Tax Preferred Stock Dividend Requirement	—	—	—	—	5
Earnings	$2,645	$2,465	$2,269	$2,296	$2,373
* Fixed Charges
Interest on Long-term Debt	$664	$618	$573	$562	$568
Amortization of Debt Discount, Premium and Expense	14	14	14	16	18
Interest Capitalized	—	—	—	—	—
Other Interest	24	24	5	143	20
Interest Component of Rentals	28	45	44	43	27
Pre-Tax Preferred Stock Dividend Requirement	—	—	—	—	5
Fixed Charges	$730	$701	$636	$764	$638
Ratio of Earnings to Fixed Charges	3.6	3.5	3.6	3.0	3.7

EX-23.1

Exhibit 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in (i) the Registration Statement on Form S-3 (No. 333-192084) relating to the Automatic Dividend Reinvestment and Cash Payment Plan; (ii) the Registration Statement on Form S-8 (No. 333-197947) relating to the Consolidated Edison, Inc. Stock Purchase Plan; (iii) the Registration Statement on Form S-8 (No. 333-108903) relating to the Consolidated Edison, Inc. Long Term Incentive Plan and Senior Executive Restricted Stock Awards; (iv) the Registration Statement on Form S-8 (No. 333-190320) relating to the Consolidated Edison, Inc. Long Term Incentive Plan; and (v) the Registration Statement on Form S-3 (No. 333-206178) relating to the Debt Securities and Common Shares of Consolidated Edison, Inc. of our report dated February 16, 2017 relating to the financial statements, financial statement schedules and the effectiveness of internal control over financial reporting, which appears in this Form 10-K.

/s/ PricewaterhouseCoopers LLP

New York, New York

February 16, 2017

EX-31.1.1

Exhibit 31.1.1

CERTIFICATIONS

I, John McAvoy, certify that:

1.I have reviewed this Annual Report on Form 10-K for the year ended December 31, 2016 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 16, 2017

/s/ John McAvoy

John McAvoy

Chairman, 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, 2016 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 16, 2017

/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, John McAvoy, 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, 2016, 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/ John McAvoy

John McAvoy

Dated: February 16, 2017

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, 2016, 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 16, 2017

EX-10.2.6.3

Exhibit 10.2.6.3

AMENDMENT ONE

TO

THE CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

SUPPLEMENTAL RETIREMENT INCOME PLAN

(As Amended and Restated Effective January 1, 2009)

In accordance with resolutions adopted by the Board of Directors of Consolidated Edison Transmission, Inc., (“CET”) on November 4, 2016 and the Board of Directors of Consolidated Edison, Inc. and the Board of Trustees of Consolidated Edison Company of New York, Inc. on November 17, 2016, approving CET’s adoption of the Consolidated Edison Company of New York, Inc. Supplemental Retirement Income Plan (the “Plan”), the undersigned hereby approves, effective as of January 1, 2017, an amendment to the Plan, adding a new Appendix A and a paragraph (a) thereunder as set forth below.

An “APPENDIX A (PARTICIPATING COMPANIES)” is hereby added to the Plan and section (a) thereunder is added as follows:

(a) Consolidated Edison Transmission, Inc. shall become a Participating Company in the Plan effective as of January 1, 2017, and its eligible employees shall be subject to the same terms and conditions as other eligible employees of the Plan.

IN WITNESS WHEREOF, the undersigned has executed this instrument this 22 day of December, 2016.

/s/ Richard Bagwell

Plan Administrator, and Vice President -

Human Resources

Consolidated Edison Company of New York, Inc.

EX-10.2.9

Exhibit 10.2.9

AMENDMENT AND RESTATEMENT

OF

THE SEVERANCE PAY PLAN

FOR MANAGEMENT EMPLOYEES

OF

CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

AND

ORANGE AND ROCKLAND UTILITIES, INC.

Effective January 1, 2017

In accordance with resolutions adopted by the Board of Directors of Consolidated Edison Transmission, Inc., (“CET”) on November 4, 2016 and the Board of Directors of Consolidated Edison, Inc. and the Board of Trustees of Consolidated Edison Company of New York, Inc. on November 17, 2016, approving CET’s adoption of the Severance Pay Plan for Management Employees of Consolidated Edison Company of New York, Inc. and Orange and Rockland Utilities, Inc. (the “Plan”), the undersigned hereby approves, effective as of January 1, 2017, an amendment and restatement of the Plan in order to carry out the foregoing resolutions, and to make certain non-material changes to the Plan for ease of administration.

IN WITNESS WHEREOF, the undersigned has executed this instrument this 22 day of December, 2016.

/s/ Richard Bagwell

Plan Administrator, and Vice President - Human Resources

Consolidated Edison Company of New York, Inc.

Exhibit 10.2.9

THE SEVERANCE PAY PLAN

FOR MANAGEMENT EMPLOYEES

OF

CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

AND

ORANGE AND ROCKLAND UTILITIES, INC.

AND

OTHER AFFLIATED ENTITIES THAT HAVE ADOPTED THE PLAN

As Amended and Restated Effective January 1, 2017

Exhibit 10.2.9

TABLE OF CONTENTS

1.Purpose; Effective Date...................................................................................................................................1

2.Type of Plan.....................................................................................................................................................1    

3.Participation.....................................................................................................................................................1

4.Eligibility...........................................................................................................................................................2

5.Exclusions........................................................................................................................................................2

6.Plan Benefits....................................................................................................................................................3

7.Effect of Plan Benefits on Other Benefits    ........................................................................................................5

8.Tax Withholding..................................................................................................................................    .............5

9.Payment Upon Death; No Payment Upon Leave of Absence.........................................................................5

10.Financing of Benefits.......................................................................................................................................6

11.Administration..................................................................................................................................................6

12.Claims Procedure............................................................................................................................................6

13.Procedure to Appeal Claim Denial...................................................................................................................7

14.Legal Service...................................................................................................................................................8

15.Benefits Not Assigned or Alienated..................................................................................................................8

16.Plan Year..........................................................................................................................................................8

17.Plan Identification Numbers.............................................................................................................................8

18.Plan Continuance............................................................................................................................................9

19.Plan Documents..............................................................................................................................................9

20.Rights of a Plan Participant.............................................................................................................................9

21.Statement of Employer’s Rights....................................................................................................................10

Exhibit 10.2.9

THE SEVERANCE PAY PLAN

FOR MANAGEMENT EMPLOYEES

OF

CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

AND

ORANGE AND ROCKLAND UTILITIES, INC.

AND

OTHER AFFLIATED ENTITIES THAT HAVE ADOPTED THE PLAN

1. Purpose; Effective Date

A.    The Severance Pay Plan for Management Employees of Consolidated Edison Company of New York Inc. and Orange and Rockland Utilities, Inc. ( the “Severance Pay Plan”) is designed to provide specified post-employment payments to eligible management employees of Consolidated Edison Company of New York, Inc. (”CECONY”) and Orange and Rockland Utilities, Inc.(“O&R”), and Consolidated Edison Transmission, Inc. (“CET”) ( collectively the “Company”).

B.    This amended and restated Severance Pay Plan is effective as of January 1, 2017 and replaces and supersedes any other management severance or separation pay plan or program currently in effect for eligible management employees of the Company.

2. Type of Plan

The Severance Pay Plan is intended to constitute an “employee welfare benefit plan” within the meaning of the provisions of the Employee Retirement Income Security Act of 1974, as amended (“ERISA”). It is intended to be a severance pay plan as defined in Federal Regulations 29 CFR 2510.3-2(b) for eligible management employees of the Company.

3. Participation

A “Participant” means a regular non-bargaining unit employee working as a full time or part time management employee of the Company, whose regularly scheduled hours of annual service are 1,000 hours or more in a 12-month period, who is on the active payroll or who is on a leave of absence with a right to reemployment. Participants shall exclude employees classified as officers of the Company, temporary workers (agency or independent), independent contractors, cooperative or student employees, employees with an agreement providing for severance benefits, or employees covered by a collective bargaining agreement that does not provide for participation in the Severance Pay Plan, even if such employees are later determined by a court of law or otherwise to constitute management employees of the Company. For purposes of the Severance Pay Plan, the Plan Administrator in his or her sole discretion shall determine who is a Participant.

4. Eligibility

In order to be eligible to receive benefits under the Severance Pay Plan, a Participant must incur an involuntary Separation from Service because of a reduction in staffing levels or any other reason which the Plan Administrator in his or her sole discretion may deem appropriate.

5. Exclusions

Benefits under this Severance Pay Plan shall not be payable to Participants who incur an involuntary Separation from Service for any of the following reasons:

(1) whose employment terminates due to death prior to the Participant’s Termination Date;

(2) who are discharged for misconduct or cause or who resign in lieu of being discharged for misconduct or cause, or who are discharged or who resign in lieu of being discharged for any other reason

Exhibit 10.2.9

except as described in Section 4 above, as determined by the Plan Administrator in his or her sole discretion;

(3) who transfer or are offered the opportunity to transfer from CECONY, O&R, or CET, as applicable to a company affiliated (directly or indirectly) with either CECONY, O&R or CET whether or not such employment is comparable;

(4) who transfer or are offered the opportunity to transfer from the Company to another employer as a result of a sale, merger, acquisition or other transaction, provided the Participant continues to perform or is offered the opportunity to continue to perform the same or similar duties immediately following the transfer, as determined by the Plan Administrator in his or her sole discretion;

(5) who are on, or whose employment is terminated as a result of or in connection with the expiration of, a sick or other authorized leave of absence; or

(6) who resign their employment with the Company for any reason.

6. Plan Benefits.

A.    For purposes of determining Plan Benefits, the following shall apply:

(1) “Salary” means a Participant’s base annual salary as of the Participant’s Termination Date, including shift differential and salary reduction contributions under Sections 125 and 401(k) of the Internal Revenue Code of 1986, as amended (the “Code”), to an employee benefit plan of the Company, but excluding bonuses, incentive compensation, overtime pay and other pay or allowances.

(2) “Equivalent Week’s Salary” means Salary divided by 52.

(3) “Section 409A” means Section 409A of the Code and the applicable rulings and regulations promulgated thereunder.

(4) “Separation from Service” means a “separation from service” from the Company as determined under the default provisions in Treasury Regulation Section 1.409A-1(h).

(5) “Termination Date” means the date of a Participant’s Separation from Service for any reason.

(6) “Years of Service” means a Participant’s completed years of service with the Company which includes a Participant’s service with CECONY, O & R or CET as applicable, ending on the Termination Date computed under the Company’s adjusted service credit rules for computing continuous service. If a Participant has previously been paid a benefit under this Severance Pay Plan, the Participant’s Years of Service will be computed from the date of the Participant’s reemployment by CECONY O&R, or CET as applicable and not from the Participant’s original continuous service date.

B. Payment.

(1) A payment will be made in one lump sum within 60 days following the Participant’s Termination Date based upon the guidelines indicated below. CECONY, O&R, or CET as applicable may pay amounts over a period of time and may pay amounts other than the indicated guidelines taking all pertinent facts and circumstances into consideration. In no event, however, shall payments be made after March 15 of the year following the year in which his or her Termination Date occurs.

Exhibit 10.2.9

Guideline A-            Guideline B-

Without a Release        With a Release

Number of Equivalent        Number of Equivalent

Years of Service Week’s SalaryWeek’s Salary

Less than 1 0 0

1 but less than 10 2 The sum of 4 and one times the number of Years of Service up to a maximum sum of 13 Equivalent Week’s Salary.

10 and over         4             The sum of 4 and one times the number of Years of

Service up to a maximum sum of 30 Equivalent Week’s

Salary.

(2) Participants who execute and deliver a release to the Company of all known and unknown claims, in such form as the Company in its sole discretion shall determine, may receive a payment based upon Guideline B in subdivision (1) above, provided that the release becomes irrevocable within the 60-day period following the Participant’s Termination Date. Participants who elect not to sign a release may receive a payment based upon Guideline A in subdivision (1) above. As additional benefits to Participants who sign a release, the Company shall offer to continue the Participant’s group health and employee group life insurance coverage with the Participant contributing the same amount as if he or she were an active employee for a period equal to the Participant’s number of Equivalent Week’s Salary. The Plan Administrator may deduct the Participant’s contributions for such continued insurance coverage from any payment made to the Participant under subdivision (1) above. Any such extended period of group health insurance coverage shall be considered part of the Participant’s COBRA continuation period of coverage. As additional benefits to Participants who sign a release the Company may provide outplacement services to such extent and level as the Company in its sole discretion shall determine, but in no event shall the outplacement service extend beyond six (6) months after the Participant’s Termination Date.

(3) If a Participant who receives a payment under this Severance Pay Plan is re-employed in a comparable position by the Company or an affiliate of the Company, the Participant shall repay to the Company any amount of the severance payment attributable to the number of Equivalent Weeks in excess of the number of weeks from the Participant’s Termination Date to the re-employment date.

(4) Notwithstanding anything herein to the contrary, if a Participant is a “Specified Employee” for purposes of Section 409A, as determined under Consolidated Edison, Inc.’s established methodology for determining Specified Employees, on the date on which such Participant incurs a Separation from Service, to the extent that any payment hereunder (including any provision or continued benefits) is deemed to be a “deferral of compensation” within the meaning of Section 409A, such payment shall not be paid or commence to be paid on any date prior to the fifteenth business day after the date that is six months following the Participant’s Separation from Service; provided, however, that a payment delayed pursuant to this clause shall commence earlier in the event of a Participant’s death prior to the end of the six-month period.

7. Effect of Plan Benefits on Other Benefits

Payment under this Severance Pay Plan will not be considered in determining a Participant’s benefits under The Consolidated Edison Retirement Plan, The Consolidated Edison Thrift Savings Plan, the Group Life Insurance Plan or any other employee benefit plan of the Company.

Exhibit 10.2.9

8. Tax Withholding

Payments made pursuant to this Severance Pay Plan are subject to the withholding of federal, state and local employment and income taxes at the time of payment and will be reported to the IRS.

9. Payment Upon Death; No Payment Upon Leave of Absence

If a Participant dies prior to the specified Termination Date, but after receiving written notification of his or her Termination Date, no payments will be made under this Severance Pay Plan to the Participant or the Participant’s heirs or estate. If a Participant dies after his or her Termination Date but before payment is made, payment will be made to the Participant’s spouse or, if the Participant leaves no surviving spouse, the Participant’s estate in a single lump sum within 60 days following the Participant’s death.

If a Participant is on sick leave or other leave of absence at the time of receiving written notification of his or her Termination Date, or if a Participant goes on sick leave or other leave of absence after receiving official notification of his or her Termination Date, the Participant’s employment and sick pay will be terminated as of the Participant’s Termination Date and payment under the Severance Pay Plan will be made within 60 days following the Termination Date.

10. Financing of Benefits

Plan Benefits for CECONY Participants shall be payable out of the CECONY’s general assets; Plan Benefits for O&R Participants shall be payable out of the O&R’s general assets; and Plan Benefits for CET Participants shall be payable out of CET’s general assets.

11. Administration

(a)    CECONY’s Vice President-Human Resources is the named fiduciary and Plan Administrator under the Severance Pay Plan who shall determine conclusively any and all questions arising from the administration of the Severance Pay Plan and shall have sole and complete discretionary authority and control to manage the operation and administration of the Severance Pay Plan, including but not limited to, the determination of all questions relating to eligibility for participation and benefits, interpretation of all Plan provisions, determination of the amount of benefits payable to any Participant, spouse, heirs or estate, all legal and factual determinations, and construction of disputed or ambiguous terms, and such determinations shall be binding on all parties.

The named fiduciary and Plan Administrator may delegate responsibilities under the Severance Pay Plan.

(b)    Section 409A. This Severance Pay Plan is intended to satisfy any applicable requirements of Section 409A and shall be performed and interpreted consistent with such intent. If the Plan Administrator determines in good faith that any provision of this Severance Pay Plan does not satisfy such requirements or could otherwise cause any party to recognize additional taxes, penalties or interest under Section 409A, the Plan Administrator will modify such provision, to the maximum extent practicable, consistent with the original intent and without violation of the requirements of Section 409A ("Section 409A Compliance"), and, notwithstanding any provision herein to the contrary, the Plan Administrator shall have broad authority to amend or to modify the Plan, without advance notice to or consent by any person, to the extent necessary or desirable to ensure Section 409A Compliance. Any determination by the Plan Administrator shall be final and binding on all parties.

12. Claims Procedure

A Participant, or any person duly authorized by such a Participant, may file a written claim for benefits under this Severance Pay Plan. Such claim may only relate to a benefit under the Severance Pay Plan and not any matter under any other policy, practice or guideline of CECONY, O&R, or CET as applicable.

The written claim shall be sent to the Plan Administrator-Severance Pay Plan, c/o Employee Benefits, Con Edison, Room 1100, 4 Irving Place, New York, New York 10003. Such claim must be received within 60 days of the event which gave rise to the claim.

Exhibit 10.2.9

If the claim is denied the claimant will receive written notice of the decision, including the specific reason for the decision, within 90 days of the date the claim was received.

In some cases, more than 90 days may be needed to make a decision. In such cases the claimant will be notified in writing, within the initial 90-day period, of the reason more time is needed. An additional 90 days may be taken to make the decision if the claimant is sent such a notice. The extension notice will show the date by which the decision will be sent.

13. Procedure to Appeal Claim Denial

The “Review Procedure” which follows gives the rules for appealing a denied claim.

(i) A claimant may use this Procedure if:

*no reply at all is received by the claimant within 90 days after filing the claim;

*a notice has extended the time an additional 90 days and no reply is received within 180 days after filing the claim; or

*written denial of the claim for benefits or other matters is received within the proper time limit and the claimant wishes to appeal the written denial.

If the claim for benefits or review of any other matter under the Severance Pay Plan is denied, the Participant, or other duly authorized person, may appeal this denial in writing within 60 days after it is received. Written request for review of any denied claim should be sent directly to the Plan Administrator-Severance Pay Plan, c/o Employee Benefits, Con Edison, Room 1100, 4 Irving Place, New York, New York 10003.

The Plan Administrator serves as the final review committee under the Severance Pay Plan for all Participants. Unless the Plan Administrator sends notice in writing that the claim is a special case needing more time, the Plan Administrator will conduct a review and decide on the appeal of the denied claim within 60 days after receipt of the written request for review. If more time is required to make a decision, the Plan Administrator will send notice in writing that there will be a delay and give the reasons for the delay. In such cases, the Plan Administrator may have 60 days more, or a total of 120 days, to make a decision.

If the claimant sends a written request for review of a denied claim, the person sending the request has the right to:

(i) review pertinent Severance Pay Plan documents which may be obtained by writing to the Plan Administrator and

(ii) send to the Plan Administrator a written statement of the issues and any other documents in support of the claim for benefits or other matters under review.

The Plan Administrator’s decision shall be given to the claimant in writing within 60 days or, if extended, 120 days, and shall include specific reasons for the decision. If the Plan Administrator does not give his decision on review within the appropriate time span, the claimant may consider the claim denied. The decision of the Plan Administrator is final and binding on all parties. If your appeal is denied, you have a right to bring a civil action, provided you have first exhausted the plan’s claims and appeal procedures described above.

A Participant in the Severance Pay Plan may have further rights under ERISA, as described in Section 20 entitled “Rights of a Plan Participant.”

14. Legal Service

Process can be served on the Severance Pay Plan Administrator by directing such service to Vice President-Human Resources, Con Edison, 4 Irving Place, New York, New York 10003.

Exhibit 10.2.9

15. Benefits Not Assigned or Alienated

Assignment or alienation of any benefits provided by the Severance Pay Plan will not be permitted or recognized except as otherwise authorized by applicable law. This means that, except as required by applicable law, benefits provided under the Severance Pay Plan may not be sold, assigned, or otherwise transferred by or on behalf of a Participant.

16. Plan Year

The Severance Pay Plan and all of its records are kept on a calendar year basis beginning January 1 and ending December 31 of each year.

17. Plan Identification Numbers

* Employer Identification Number 13-5009340

* Plan Number 557

18. Plan Continuance

CECONY may amend or terminate this Severance Pay Plan at any time. Any amendments or the termination of the Severance Pay Plan shall not result in the forfeiture of the benefits previously awarded under the Severance Pay Plan.

19. Plan Documents

This document serves as both the Severance Pay Plan and a Summary Plan Description as such terms are defined in ERISA.

20. Rights of a Plan Participant

As a Participant in this Severance Pay Plan, you are entitled to certain rights and protection under the Employee Retirement Income Security Act of 1974 (ERISA). ERISA provides that all Severance Pay Plan Participants shall be entitled to:

(i) Examine, without charge, all Severance Pay Plan documents and copies of all documents filed by the Severance Pay Plan with the U.S. Department of Labor, such as annual reports filed with the U.S. Department of Labor and available at the Public Disclosure Room of the Employee Benefits Security Administration.

(ii) Obtain copies of all Severance Pay Plan documents and other Plan information upon written request to the Severance Pay Plan Administrator. There may be a reasonable charge for such copies.

In addition to creating rights for Severance Pay Plan Participants, ERISA imposes duties upon these who are responsible for the operation of employee benefit plans. The people who operate your Severance Pay Plan, called “Fiduciaries” of the Plan, have a duty to do so prudently and in the interest of you and other Severance Pay Plan Participants. No one, including your employer, or any other person, may terminate your employment or otherwise discriminate against you in any way to prevent you from obtaining a benefit or exercising your right under ERISA. If your claim for benefits is denied, in whole or in part, you have certain rights of review as described under Claims and Procedure to Appeal Claim Denial Sections 12 and 13, respectively, of this Plan.

Under ERISA, there are steps you can take to enforce the above rights. For instance, if you request materials from the Plan Administrator and do not receive them within 30 days, you may file suit in a federal court. In such case, the court may require the Plan Administrator to provide the materials and pay up to $110 a day until you receive the materials, unless the materials were not sent because of reasons beyond the control of the Plan Administrator. If you have a claim for benefits which is denied or ignored, in whole or in part, you may file suit in a state or federal court. If you are discriminated against for asserting your rights, you may seek assistance from the U.S. Department of Labor or you may file suit in a federal court. The court will decide who will pay court costs and legal fees. If you are successful, the court may order the

Exhibit 10.2.9

person you have sued to pay these costs and fees. If you lose, the court may order you to pay these costs and fees if, for example, it finds your claim is frivolous.

If you have any questions about the Severance Pay Plan, you should contact the Severance Pay Plan Fiduciary. If you have any questions about this statement of your rights, or about your rights under ERISA, you should contact your nearest Area Office of the Employee Benefits Security Administration, U. S. Department of Labor.

21. Statement of Employer’s Rights

A Participant’s eligibility for benefits under this Severance Pay Plan shall not be considered a guarantee of continued or lifetime employment with the Company and shall not change the fact that a Participant shall be considered an employee at will. A Participant’s employment by the Company may be terminated by the Company whenever the Company in its sole discretion considers that to be in its best interest, subject to applicable law.

22. Effect on Invalidity of Any Part of the Severance Pay Plan

The invalidity or enforceability of any provision hereof shall in no way affect the validity or enforceability of any other provision.

23. Choice of Law and Forum

Except to the extent federal law applies, this Severance Pay Plan shall be governed by the laws of the State of New York without giving effect to the State’s principles of conflicts of laws. The Participants further consents to the selection of New York State and the United States courts situated within the borough of Manhattan, New York, as the exclusive forums for any legal proceeding arising from or relating to this Plan.

EX-10.2.10.3

Exhibit 10.2.10.3

AMENDMENT ONE

TO

THE CONSOLIDATED EDISON COMPANY OF NEW YORK, INC.

DEFERRED INCOME PLAN

(Effective January 1, 2013)

In accordance with resolutions adopted by the Board of Directors of Consolidated Edison Transmission, Inc., (“CET”) on November 4, 2016 and the Board of Directors of Consolidated Edison, Inc. and the Board of Trustees of Consolidated Edison Company of New York, Inc. on November 17, 2016, approving CET’s adoption of the Consolidated Edison Company of New York, Inc. Deferred Income Plan (the “Plan”), the undersigned hereby approves, effective as of January 1, 2017, the amendments to the Plan set forth below.

1. Section 1.16 Company is amended by adding the following to the end thereof:

“Company” shall also include any Affiliated Company listed in Appendix A that has adopted the Plan.

2. An “APPENDIX A (Affiliated Companies that have adopted the Plan)” is hereby added to the Plan and section (a) thereunder is added as follows:

(a) Consolidated Edison Transmission, Inc. shall become a Participating Company in the Plan effective as of January 1, 2017, and its eligible employees shall be subject to the same terms and conditions as other eligible employees of the Plan.

IN WITNESS WHEREOF, the undersigned has executed this instrument this 22 day of December, 2016.

/s/ Richard Bagwell

Plan Administrator, and Vice President -

Human Resources

Consolidated Edison Company of New York, Inc.

EX-12.2

Exhibit 12.2

Consolidated Edison Company of New York, Inc.

Ratio of Earnings to Fixed Charges

(Millions of Dollars)

	For the Years Ended December 31,
	2016	2015	2014	2013	2012
Earnings
Net Income	$1,056	$1,084	$1,058	$1,020	$1,014
Preferred Stock Dividend	—	—	—	—	3
(Income) or Loss from Equity Investees	—	—	—	—	—
Minority Interest Loss	—	—	—	—	—
Income Tax	603	574	555	520	529
Pre-Tax Income	$1,659	$1,658	$1,613	$1,540	$1,546
Add: Fixed Charges*	634	629	580	564	573
Add: Distributed Income of Equity Investees	—	—	—	—	—
Subtract: Interest Capitalized	—	—	—	—	—
Subtract: Pre-Tax Preferred Stock Dividend Requirement	—	—	—	—	—
Earnings	$2,293	$2,287	$2,193	$2,104	$2,119
* Fixed Charges
Interest on Long-term Debt	$575	$553	$510	$496	$508
Amortization of Debt Discount, Premium and Expense	13	14	13	15	17
Interest Capitalized	—	—	—	—	—
Other Interest	19	19	15	11	22
Interest Component of Rentals	27	43	42	42	26
Pre-Tax Preferred Stock Dividend Requirement	—	—	—	—	—
Fixed Charges	$634	$629	$580	$564	$573
Ratio of Earnings to Fixed Charges	3.6	3.6	3.8	3.7	3.7

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. 333-206177) of Consolidated Edison Company of New York, Inc. of our report dated February 16, 2017 relating to the financial statements, financial statement schedule and the effectiveness of internal control over financial reporting, which appears in this Form 10-K.

/s/ PricewaterhouseCoopers LLP

New York, New York

February 16, 2017

EX-31.2.1

Exhibit 31.2.1

CERTIFICATIONS

I, John McAvoy, certify that:

1.I have reviewed this Annual Report on Form 10-K for the year ended December 31, 2016 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 16, 2017

/s/ John McAvoy

John McAvoy

Chairman and 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, 2016 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 16, 2017

/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, John McAvoy, 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, 2016, 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/ John McAvoy

John McAvoy

Dated: February 16, 2017

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, 2016, 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 16, 2017

XML

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2016	Jan. 31, 2017	Jun. 30, 2016
Document Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	FY
Trading Symbol	ED
Entity Registrant Name	CONSOLIDATED EDISON INC
Entity Central Index Key	0001047862
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		305,059,148
Entity Public Float			$ 24.5
CECONY
Document Information [Line Items]
Entity Registrant Name	CONSOLIDATED EDISON CO OF NEW YORK INC
Entity Central Index Key	0000023632
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer

XML

Consolidated Income Statement - USD ($) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
OPERATING REVENUES
Electric	$ 8,741	$ 8,832	$ 9,114
Gas	1,692	1,709	1,933
Steam	551	629	628
Non-utility	1,091	1,384	1,244
TOTAL OPERATING REVENUES	12,075	12,554	12,919
OPERATING EXPENSES
Purchased power	2,439	2,973	3,417
Fuel	172	248	285
Gas purchased for resale	477	495	811
Other operations and maintenance	3,269	3,344	3,294
Depreciation and amortization	1,216	1,130	1,071
Taxes, other than income taxes	2,031	1,937	1,877
TOTAL OPERATING EXPENSES	9,604	10,127	10,755
Gain on sale of retail electric supply business and solar electric production projects	104	0	45
OPERATING INCOME	2,575	2,427	2,209
OTHER INCOME (DEDUCTIONS)
Investment and other income	91	35	54
Allowance for equity funds used during construction	10	5	2
Other deductions	(37)	(16)	(14)
TOTAL OTHER INCOME (DEDUCTIONS)	64	24	42
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,639	2,451	2,251
INTEREST EXPENSE
Interest on long-term debt	678	632	587
Other interest	24	24	5
Allowance for borrowed funds used during construction	(6)	(3)	(1)
NET INTEREST EXPENSE	696	653	591
INCOME BEFORE INCOME TAX EXPENSE	1,943	1,798	1,660
INCOME TAX EXPENSE	698	605	568
NET INCOME	$ 1,245	$ 1,193	$ 1,092
Net income per common share — basic (dollars per share)	$ 4.15	$ 4.07	$ 3.73
Net income per common share — diluted (dollars per share)	4.12	4.05	3.71
DIVIDENDS DECLARED PER COMMON SHARE (dollars per share)	$ 2.68	$ 2.60	$ 2.52
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (IN MILLIONS)	300.4	293.0	292.9
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (IN MILLIONS)	301.9	294.4	294.0
CECONY
OPERATING REVENUES
Electric	$ 8,106	$ 8,172	$ 8,437
Gas	1,508	1,527	1,721
Steam	551	629	628
TOTAL OPERATING REVENUES	10,165	10,328	10,786
OPERATING EXPENSES
Purchased power	1,568	1,719	2,091
Fuel	172	248	285
Gas purchased for resale	319	337	609
Other operations and maintenance	2,806	2,881	2,873
Depreciation and amortization	1,106	1,040	991
Taxes, other than income taxes	1,932	1,856	1,798
TOTAL OPERATING EXPENSES	7,903	8,081	8,647
OPERATING INCOME	2,262	2,247	2,139
OTHER INCOME (DEDUCTIONS)
Investment and other income	8	5	22
Allowance for equity funds used during construction	8	4	1
Other deductions	(16)	(14)	(12)
TOTAL OTHER INCOME (DEDUCTIONS)	0	(5)	11
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	2,262	2,242	2,150
INTEREST EXPENSE
Interest on long-term debt	588	567	523
Other interest	19	19	15
Allowance for borrowed funds used during construction	(4)	(2)	(1)
NET INTEREST EXPENSE	603	584	537
INCOME BEFORE INCOME TAX EXPENSE	1,659	1,658	1,613
INCOME TAX EXPENSE	603	574	555
NET INCOME	$ 1,056	$ 1,084	$ 1,058

XML

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
NET INCOME	$ 1,245	$ 1,193	$ 1,092
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	7	11	(20)
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	7	11	(20)
COMPREHENSIVE INCOME	1,252	1,204	1,072
CECONY
NET INCOME	1,056	1,084	1,058
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	2	2	(5)
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	2	2	(5)
COMPREHENSIVE INCOME	$ 1,058	$ 1,086	$ 1,053

XML

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
OPERATING ACTIVITIES
Net income	$ 1,245	$ 1,193	$ 1,092
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,216	1,130	1,071
Deferred income taxes	783	653	518
Rate case amortization and accruals	(210)	(52)	121
Common equity component of allowance for funds used during construction	(10)	(5)	(2)
Net derivative (gains)/losses	(6)	3	128
Pre-tax gain on sale of retail electric supply business and solar electric production projects	(104)	0	(45)
Other non-cash items, net	142	77	(35)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(69)	96	44
Materials and supplies, including fuel oil and gas in storage	13	22	(10)
Other receivables and other current assets	54	(27)	316
Income taxes receivable	87	58	(224)
Prepayments	20	(14)	(27)
Accounts payable	29	(79)	(9)
Pensions and retiree benefits obligations, net	609	756	822
Pensions and retiree benefits contributions	(515)	(756)	(584)
Accrued taxes	2	(10)	(404)
Accrued interest	14	4	(113)
Superfund and environmental remediation costs, net	69	22	28
Distributions from equity investments	68	31	0
System benefit charge	244	38	(37)
Deferred charges, noncurrent assets and other regulatory assets	(97)	(111)	(361)
Deferred credits and other regulatory liabilities	(68)	182	498
Other current and noncurrent liabilities	(57)	66	44
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,459	3,277	2,831
INVESTING ACTIVITIES
Utility construction expenditures	(2,835)	(2,562)	(2,239)
Cost of removal less salvage	(206)	(219)	(216)
Non-utility construction expenditures	(845)	(492)	(180)
Proceeds from grants related to solar electric production projects	0	0	36
Proceeds from sale of assets	252	0	108
Restricted cash	(17)	(13)	15
Proceeds from the transfer of assets to NY Transco	122	0	0
Other investing activities	31	(72)	10
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,976)	(3,657)	(2,759)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(475)	729	(651)
Issuance of long-term debt	2,590	1,147	1,850
Retirement of long-term debt	(735)	(500)	(480)
Debt issuance costs	(24)	(15)	(17)
Common stock dividends	(763)	(733)	(739)
Issuance of common shares - public offering	702	0	0
Issuance of common shares for stock plans, net of repurchases	51	1	(10)
Distribution to noncontrolling interest	(1)	0	0
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	1,345	629	(47)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(172)	249	25
BALANCE AT BEGINNING OF PERIOD	944	699	674
BALANCE AT END OF PERIOD	772	948	699
LESS: CHANGE IN CASH BALANCES HELD FOR SALE	(4)	4	0
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	776	944	699
Cash paid/(received) during the period for:
Interest	664	597	561
Income taxes	(180)	(36)	633
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	388	279	179
Issuance of common shares for dividend reinvestment	46	28	11
Debt assumed with business acquisitions	195	0	0
Electric and Gas Transmission Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(1,076)	0	0
Renewable Electric Production Projects
INVESTING ACTIVITIES
Investments in/acquisitions of projects	(402)	(299)	(293)
CECONY
OPERATING ACTIVITIES
Net income	1,056	1,084	1,058
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	1,106	1,040	991
Deferred income taxes	545	449	331
Rate case amortization and accruals	(227)	(74)	102
Common equity component of allowance for funds used during construction	(8)	(4)	(1)
Other non-cash items, net	(31)	(27)	(33)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable - customers	(23)	87	59
Materials and supplies, including fuel oil and gas in storage	18	24	(12)
Other receivables and other current assets	(11)	38	48
Accounts receivables from affiliated companies	81	(58)	(13)
Prepayments	13	13	(24)
Accounts payable	20	(51)	(57)
Accounts payable to affiliated companies	(2)	(11)	(22)
Pensions and retiree benefits obligations, net	579	714	742
Pensions and retiree benefits contributions	(476)	(703)	(544)
Accrued taxes	1	3	0
Accrued taxes to affiliated companies	117	(8)	(403)
Accrued interest	(7)	1	(22)
Superfund and environmental remediation costs, net	79	19	32
System benefit charge	221	38	(38)
Deferred charges, noncurrent assets and other regulatory assets	(172)	(150)	(334)
Deferred credits and other regulatory liabilities	179	379	475
Other current and noncurrent liabilities	(20)	16	95
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,038	2,819	2,430
INVESTING ACTIVITIES
Utility construction expenditures	(2,672)	(2,410)	(2,094)
Cost of removal less salvage	(203)	(212)	(210)
Restricted cash	14	(16)	0
Proceeds from the transfer of assets to NY Transco	122	0	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,739)	(2,638)	(2,304)
FINANCING ACTIVITIES
Net (payment)/issuance of short-term debt	(433)	583	(760)
Issuance of long-term debt	1,300	650	1,850
Retirement of long-term debt	(650)	(350)	(475)
Debt issuance costs	(13)	(7)	(17)
Capital contribution by parent	100	13	0
Dividend to parent	(744)	(872)	(712)
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	(440)	17	(114)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CHANGE FOR THE PERIOD	(141)	198	12
BALANCE AT BEGINNING OF PERIOD	843	645	633
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	702	843	645
Cash paid/(received) during the period for:
Interest	581	554	504
Income taxes	(162)	163	748
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$ 295	$ 210	$ 151

XML

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
CURRENT ASSETS
Cash and temporary cash investments	$ 776	$ 944
Accounts receivable - customers, less allowance for uncollectible accounts	1,106	1,052
Other receivables, less allowance for uncollectible accounts	195	304
Income taxes receivable	79	166
Accrued unbilled revenue	447	360
Fuel oil, gas in storage, materials and supplies, at average cost	339	350
Prepayments	159	177
Regulatory assets	100	132
Assets held for sale	0	157
Other current assets	205	194
TOTAL CURRENT ASSETS	3,406	3,836
INVESTMENTS	1,921	884
UTILITY PLANT, AT ORIGINAL COST
General	2,719	2,622
TOTAL	40,411	38,174
Less: Accumulated depreciation	8,541	8,044
Net	31,870	30,130
Construction work in progress	1,175	1,003
NET UTILITY PLANT	33,045	31,133
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	1,482	832
Construction work in progress	689	244
NET PLANT	35,216	32,209
OTHER NONCURRENT ASSETS
Goodwill	428	429
Intangible assets, less accumulated amortization of $6 and $4 in 2016 and 2015, respectively	124	2
Regulatory assets	7,024	8,096
Other deferred charges and noncurrent assets	136	186
TOTAL OTHER NONCURRENT ASSETS	7,712	8,713
TOTAL ASSETS	48,255	45,642
CURRENT LIABILITIES
Long-term debt due within one year	39	739
Notes payable	1,054	1,529
Accounts payable	1,147	1,008
Customer deposits	352	354
Accrued taxes	64	62
Accrued interest	150	136
Accrued wages	101	97
Fair value of derivative liabilities	77	66
Regulatory liabilities	128	115
Liabilities held for sale	0	89
System benefit charge	434	190
Other current liabilities	297	335
TOTAL CURRENT LIABILITIES	3,843	4,720
NONCURRENT LIABILITIES
Provision for injuries and damages	160	185
Pensions and retiree benefits	1,847	2,911
Superfund and other environmental costs	753	765
Asset retirement obligations	246	242
Fair value of derivative liabilities	40	39
Deferred income taxes and unamortized investment tax credits	10,205	9,537
Regulatory liabilities	1,905	1,977
Other deferred credits and noncurrent liabilities	215	199
TOTAL NONCURRENT LIABILITIES	15,371	15,855
LONG-TERM DEBT	14,735	12,006
EQUITY
Common shareholders’ equity	14,298	13,052
Noncontrolling interest	8	9
TOTAL EQUITY (See Statement of Equity)	14,306	13,061
TOTAL LIABILITIES AND EQUITY	48,255	45,642
Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	27,747	26,358
Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	7,524	6,858
Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	2,421	2,336
CECONY
CURRENT ASSETS
Cash and temporary cash investments	702	843
Accounts receivable - customers, less allowance for uncollectible accounts	1,032	987
Other receivables, less allowance for uncollectible accounts	81	70
Accrued unbilled revenue	399	327
Accounts receivable from affiliated companies	109	190
Fuel oil, gas in storage, materials and supplies, at average cost	270	288
Prepayments	100	113
Regulatory assets	90	121
Other current assets	97	133
TOTAL CURRENT ASSETS	2,880	3,072
INVESTMENTS	315	286
UTILITY PLANT, AT ORIGINAL COST
General	2,490	2,411
TOTAL	37,847	35,766
Less: Accumulated depreciation	7,836	7,378
Net	30,011	28,388
Construction work in progress	1,104	922
NET UTILITY PLANT	31,115	29,310
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation	4	5
NET PLANT	31,119	29,315
OTHER NONCURRENT ASSETS
Goodwill	245	245
Regulatory assets	6,473	7,482
Other deferred charges and noncurrent assets	69	75
TOTAL OTHER NONCURRENT ASSETS	6,542	7,557
TOTAL ASSETS	40,856	40,230
CURRENT LIABILITIES
Long-term debt due within one year	0	650
Notes payable	600	1,033
Accounts payable	876	771
Accounts payable to affiliated companies	10	12
Customer deposits	336	339
Accrued taxes	50	49
Accrued taxes to affiliated companies	119	2
Accrued interest	111	118
Accrued wages	91	88
Fair value of derivative liabilities	66	50
Regulatory liabilities	90	84
System benefit charge	398	177
Other current liabilities	242	266
TOTAL CURRENT LIABILITIES	2,989	3,639
NONCURRENT LIABILITIES
Provision for injuries and damages	154	178
Pensions and retiree benefits	1,544	2,565
Superfund and other environmental costs	655	665
Asset retirement obligations	227	234
Fair value of derivative liabilities	33	36
Deferred income taxes and unamortized investment tax credits	9,450	8,755
Regulatory liabilities	1,712	1,789
Other deferred credits and noncurrent liabilities	190	167
TOTAL NONCURRENT LIABILITIES	13,965	14,389
LONG-TERM DEBT	12,073	10,787
EQUITY
Common shareholders’ equity	11,829	11,415
TOTAL LIABILITIES AND EQUITY	40,856	40,230
CECONY | Electric
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	26,122	24,828
CECONY | Gas
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	6,814	6,191
CECONY | Steam
UTILITY PLANT, AT ORIGINAL COST
Utility plant, at original cost	$ 2,421	$ 2,336

XML

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Accounts receivable - customers, allowance for uncollectible accounts	$ 69	$ 85
Other receivables, allowance for uncollectible accounts	14	11
Non-utility property, accumulated depreciation	140	95
Intangible assets, accumulated amortization	6	4
CECONY
Accounts receivable - customers, allowance for uncollectible accounts	65	80
Other receivables, allowance for uncollectible accounts	13	11
Non-utility property, accumulated depreciation	$ 25	$ 25

XML

Consolidated Statement of Shareholders' 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, 2013		293,000,000								235,000,000
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2013	$ 12,245	$ 32	$ 4,995	$ 8,338	$ (1,034)	$ (61)	$ (25)	$ 0
BALANCE AS OF BEGINNING OF PERIOD at Dec. 31, 2013									$ 10,847	$ 589	$ 4,234	$ 7,053	$ (962)	$ (61)	$ (6)
TREASURY STOCK, BALANCE AS OF BEGINNING OF PERIOD (in shares) at Dec. 31, 2013					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,092			1,092					1,058			1,058
Common stock dividends	(739)			(739)					(712)			(712)
Issuance of common shares for stock plans, net of repurchases (in shares)		0			0
Issuance of common shares for stock plans, net of repurchases	(2)		(4)		$ 2
Other comprehensive income (loss)	(20)						(20)		(5)						(5)
Noncontrolling interest	9							9
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2014		293,000,000								235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2014	12,585	$ 32	4,991	8,691	$ (1,032)	(61)	(45)	9							(11)
BALANCE AS OF END OF PERIOD at Dec. 31, 2014									11,188	$ 589	4,234	7,399	(962)	(61)	(11)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2014					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,193			1,193					1,084			1,084
Common stock dividends	(761)			(761)					(872)			(872)
Issuance of common shares for stock plans, net of repurchases (in shares)		0			0
Issuance of common shares for stock plans, net of repurchases	33		39		$ (6)
Capital contribution by parent									13		13
Other comprehensive income (loss)	11						11		2						2
Noncontrolling interest	0							0
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2015		293,000,000								235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2015	13,061	$ 32	5,030	9,123	$ (1,038)	(61)	(34)	9							(9)
BALANCE AS OF END OF PERIOD at Dec. 31, 2015	13,052								11,415	$ 589	4,247	7,611	(962)	(61)	(9)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2015					23,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,245			1,245					1,056			1,056
Common stock dividends	(809)			(809)					(744)			(744)
Issuance of common shares - public offering (in shares)		10,000,000
Issuance of common shares - public offering	702	$ 1	723			(22)
Issuance of common shares for stock plans (in shares)		2,000,000
Issuance of common shares for stock plans	101		101
Capital contribution by parent									100		100
Other comprehensive income (loss)	7						7		$ 2						2
Noncontrolling interest	(1)							(1)
BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2016		305,000,000							21,976,200	235,000,000
BALANCE AS OF END OF PERIOD at Dec. 31, 2016	14,306	$ 33	$ 5,854	$ 9,559	$ (1,038)	$ (83)	$ (27)	$ 8							(7)
BALANCE AS OF END OF PERIOD at Dec. 31, 2016	$ 14,298								$ 11,829	$ 589	$ 4,347	$ 7,923	$ (962)	$ (61)	$ (7)
TREASURY STOCK, BALANCE AS OF END OF PERIOD (in shares) at Dec. 31, 2016					23,000,000

XML

Consolidated Statement of Capitalization - USD ($) shares in Millions, $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Schedule of Capitalization, Equity [Line Items]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	305	293
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS	$ 14,325	$ 13,086
Pension plan liability adjustments, net of taxes	(24)	(31)
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	(3)	(3)
TOTAL ACCUMULATED OTHER COMPREHENSIVE LOSS, NET OF TAXES	(27)	(34)
Equity	14,298	13,052
Noncontrolling interest	8	9
TOTAL EQUITY (See Statement of Equity)	$ 14,306	$ 13,061
CECONY
Schedule of Capitalization, Equity [Line Items]
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS (in shares)	235	235
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS	$ 11,836	$ 11,424
Pension plan liability adjustments, net of taxes	(4)	(6)
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	(3)	(3)
TOTAL ACCUMULATED OTHER COMPREHENSIVE LOSS, NET OF TAXES	(7)	(9)
Equity	11,829	11,415
TOTAL SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	$ 11,829	$ 11,415

XML

Consolidated Statement of Capitalization - Long-term Debt - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Schedule of Capitalization, Long-term Debt [Line Items]
Other long-term debt		$ 317	$ 323
Unamortized debt expense		(107)	(91)
Unamortized debt discount		(27)	(22)
TOTAL		14,774	12,745
Long-term debt - Variable rate term loan		400	0
Less: Long-term debt due within one year		39	739
TOTAL LONG-TERM DEBT		14,735	12,006
TOTAL CAPITALIZATION		29,033	25,058
CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Unamortized debt expense		(87)	(78)
Unamortized debt discount		(26)	(21)
TOTAL		12,073	11,437
Less: Long-term debt due within one year		0	650
TOTAL LONG-TERM DEBT		12,073	10,787
TOTAL CAPITALIZATION		23,902	22,202
Coram
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 180	0
Coram | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.52%
Texas Solar 4
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 64	64
Texas Solar 4 | Minimum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.95%
Texas Solar 4 | Maximum
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.25%
California Solar 2
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.94%
TOTAL		$ 114	115
California Solar 3
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.07%
TOTAL		$ 95	0
Texas Solar 5
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.53%
TOTAL		$ 158	159
Texas Solar 7
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.21%
TOTAL		$ 218	0
Other project debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		16	1
Project Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		845	339
Debentures
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		12,260	11,110
Debentures | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 11,100	10,450
Debentures | Debenture Series 2006A, 5.45% Due 2016
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.45%
TOTAL		$ 0	75
Debentures | Debenture Series 2006C, 5.50% Due 2016
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 0	400
Debentures | Debenture Series 2006C, 5.50% Due 2016 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 0	400
Debentures | Debenture Series 2006D, 5.30% Due 2016
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.30%
TOTAL		$ 0	250
Debentures | Debenture Series 2006D, 5.30% Due 2016 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.30%
TOTAL		$ 0	250
Debentures | Debenture Series 2008A, 5.85% Due 2018
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.85%
TOTAL		$ 600	600
Debentures | Debenture Series 2008A, 5.85% Due 2018 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.85%
TOTAL		$ 600	600
Debentures | Debenture Series 2008A, 6.15% Due 2018
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.15%
TOTAL		$ 50	50
Debentures | Debenture Series 2008C, 7.125% Due 2018
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		7.125%
TOTAL		$ 600	600
Debentures | Debenture Series 2008C, 7.125% Due 2018 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		7.125%
TOTAL		$ 600	600
Debentures | Debenture Series 2009A, 4.96% Due 2019
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.96%
TOTAL		$ 60	60
Debentures | Debenture Series 2009B, 6.65% Due 2019
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.65%
TOTAL		$ 475	475
Debentures | Debenture Series 2009B, 6.65% Due 2019 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.65%
TOTAL		$ 475	475
Debentures | Debenture Series 2010A, 4.45% Due 2020
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 350	350
Debentures | Debenture Series 2010A, 4.45% Due 2020 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 350	350
Debentures | Debenture Series 2016A, 2.00% Due 2021
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.00%
TOTAL		$ 500	0
Debentures | Debenture Series 2014B, 3.30% Due 2024
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.30%
TOTAL		$ 250	250
Debentures | Debenture Series 2014B, 3.30% 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	0
Debentures | Debenture Series 2016B, 2.90% Due 2026 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		2.90%
TOTAL		$ 250	0
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 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 Series 2008B, 6.75% Due 2038
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.75%
TOTAL		$ 600	600
Debentures | Debenture Series 2008B, 6.75% Due 2038 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.75%
TOTAL		$ 600	600
Debentures | Debenture Series 2009B, 6.00% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		6.00%
TOTAL		$ 60	60
Debentures | Debenture Series 2009C, 5.50% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 600	600
Debentures | Debenture Series 2009C, 5.50% Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 600	600
Debentures | Debenture Series 2010B, 5.70% Due 2040
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 350	350
Debentures | Debenture Series 2010B, 5.70% Due 2040 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.70%
TOTAL		$ 350	350
Debentures | Debenture Series 2010B, 5.50% Due 2040
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		5.50%
TOTAL		$ 115	115
Debentures | Debenture Series 2012A, 4.20% Due 2042
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.20%
TOTAL		$ 400	400
Debentures | Debenture Series 2012A, 4.20% Due 2042 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.20%
TOTAL		$ 400	400
Debentures | Debenture Series 2013A, 3.95% Due 2043
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 700	700
Debentures | Debenture Series 2013A, 3.95% Due 2043 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.95%
TOTAL		$ 700	700
Debentures | Debenture Series 2014A, 4.45% Due 2044
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 850	850
Debentures | Debenture Series 2014A, 4.45% Due 2044 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.45%
TOTAL		$ 850	850
Debentures | Debenture Series 2015A, 4.50% due 2045
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 650	650
Debentures | Debenture Series 2015A, 4.50% due 2045 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.50%
TOTAL		$ 650	650
Debentures | Debenture Series 2015A, 4.95% 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 Series 2016A, 3.85% Due 2046
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.85%
TOTAL		$ 550	0
Debentures | Debenture Series 2016A, 3.85% Due 2046 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.85%
TOTAL		$ 550	0
Debentures | Debenture Series 2016A. 3.88% Due 2046
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		3.88%
TOTAL		$ 75	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
Debentures | Debenture Series 2016C, 4.30% Due 2056 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		4.30%
TOTAL		$ 500	0
Tax-Exempt Debt
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL	[1]	1,086	1,086
Tax-Exempt Debt | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
TOTAL		$ 1,086	1,086
Tax-Exempt Debt | Tax Exempt Debt Series 2004B Series 1, 0.98% due 2032
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	0.98%
TOTAL	[1]	$ 127	127
Tax-Exempt Debt | Tax Exempt Debt Series 2004B Series 1, 0.98% due 2032 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.98%
TOTAL		$ 127	127
Tax-Exempt Debt | Tax Exempt Debt Series 1999A, 0.98% Due 2034
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	0.98%
TOTAL	[1]	$ 293	293
Tax-Exempt Debt | Tax Exempt Debt Series 1999A, 0.98% Due 2034 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.98%
TOTAL		$ 293	293
Tax-Exempt Debt | Tax Exempt Debt Series 2004B Series 2, 0.998% Due 2035
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	0.998%
TOTAL	[1]	$ 20	20
Tax-Exempt Debt | Tax Exempt Debt Series 2004B Series 2, 0.998% Due 2035 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.998%
TOTAL		$ 20	20
Tax-Exempt Debt | Tax Exempt Debt Series 2001B, 1.134% due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	1.134%
TOTAL	[1]	$ 98	98
Tax-Exempt Debt | Tax Exempt Debt Series 2001B, 1.134% due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		1.134%
TOTAL		$ 98	98
Tax-Exempt Debt | Tax Exempt Debt Series 2010A, 0.745% due 2036
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	0.745%
TOTAL	[1]	$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2010A, 0.745% due 2036 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.745%
TOTAL		$ 225	225
Tax-Exempt Debt | Tax Exempt Debt Series 2004A, 0.963% due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	0.963%
TOTAL	[1]	$ 98	98
Tax-Exempt Debt | Tax Exempt Debt Series 2004A, 0.963% due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.963%
TOTAL		$ 98	98
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 0.74% due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	0.74%
TOTAL	[1]	$ 99	99
Tax-Exempt Debt | Tax Exempt Debt Series 2004C, 0.74% due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.74%
TOTAL		$ 99	99
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 0.723% Due 2039
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate	[1]	0.723%
TOTAL	[1]	$ 126	126
Tax-Exempt Debt | Tax-Exempt Debt Series 2005A, 0.723% Due 2039 | CECONY
Schedule of Capitalization, Long-term Debt [Line Items]
Interest Rate		0.723%
TOTAL		$ 126	$ 126

[1] Rates are to be reset weekly or by auction held every 35 days; December 31, 2016 rates shown.

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General

12 Months Ended

Dec. 31, 2016

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. The Clean Energy Businesses, Inc. has three subsidiaries: Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company that provides energy-related products and services to retail customers. Con Edison Transmission, Inc. invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas). See Note U.

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Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2016

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Principles of Consolidation

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

Accounting Policies

The accounting policies of Con Edison and its subsidiaries conform to 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. The Utilities are receiving or being credited with a return on all of their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on all of their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable state regulators.

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

Plant and Depreciation

Utility Plant

Utility plant is stated at original cost. The cost of repairs and maintenance is charged to expense and the cost of betterments is capitalized. The capitalized cost of additions to utility plant includes indirect costs such as engineering, supervision, payroll taxes, pensions, other benefits and an allowance for funds used during construction (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 R.

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 4.7 percent, 4.4 percent and 1.6 percent for 2016, 2015 and 2014, respectively. The AFUDC rates for O&R were 3.5 percent, 0.4 percent and 2.6 percent for 2016, 2015 and 2014, 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 3.1 percent for 2016, 2015 and 2014. The average depreciation rates for O&R were 2.9 percent, 3.0 percent and 2.9 percent for 2016, 2015 and 2014, respectively.

The estimated lives for utility plant for CECONY range from 5 to 85 years for electric and 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, 2016 and 2015, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Electric
Generation	$479	$459	$479	$459
Transmission	3,184	3,045	2,963	2,833
Distribution	18,150	17,244	17,234	16,394
Gas (a)	6,285	5,698	5,749	5,196
Steam	1,882	1,849	1,882	1,849
General	1,816	1,758	1,639	1,592
Held for future use	74	77	65	65
Construction work in progress	1,175	1,003	1,104	922
Net Utility Plant	$33,045	$31,133	$31,115	$29,310

(a) Primarily distribution.

Under the Utilities’ rate plans, the aggregate annual depreciation allowance in effect at December 31, 2016 was $1,176 million, including $1,106 million under CECONY’s electric, gas and steam rate plans that have been approved by the New York State Public Service Commission (NYSPSC).

Non-Utility Plant

Non-utility plant is stated at original cost. For Con Edison, non-utility plant consists primarily of the Clean Energy Businesses’ renewable electric production and gas storage. 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 range from 3 to 30 years.

Goodwill

Con Edison tests 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 two-step, quantitative goodwill impairment test. However, Con Edison has not elected to perform the qualitative assessment and exclusively applies the two-step quantitative approach. The first step of the goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, the second step is performed to measure the amount of impairment loss, if any. The second step requires a calculation of the implied fair value of goodwill. In 2016, Con Edison Solutions recorded a $15 million impairment charge on goodwill. See Note K.

Long-Lived and Intangible Assets

Con Edison evaluates the impairment of long-lived assets and intangible assets with definite lives, based on projections of undiscounted future cash flows, whenever events or changes in circumstances indicate that the carrying amounts of such assets may not be recoverable. In the event an evaluation indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are written down to their estimated fair value. In 2015, Con Edison recorded a $5 million impairment charge on the assets held for sale of Pike County Light & Power Company (Pike), a former O&R subsidiary that was sold in August 2016 (see Note U). No impairment charges on long-lived assets were recognized in 2016 or 2014. No impairment charges on intangible assets with definite lives were recognized in 2016, 2015, or 2014. For information about the Companies' intangible assets, see Note K.

Revenues

The Utilities recognize and, until the sale of its retail electric supply business in September 2016 (see Note U), Con Edison Solutions recognized revenues for energy service on a monthly billing cycle basis. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers. The Utilities accrue and Con Edison Solutions accrued revenues at the end of each month for estimated energy service not yet billed to customers.

CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism under which the company’s actual energy delivery revenues are compared 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)	2016	2015	2014
Con Edison	$336	$354	$365
CECONY	316	331	343

For information about changes to the accounting rules for revenue recognition, see Note T.

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

Investments consist primarily of the investments of Con Edison Transmission and the Clean Energy Businesses 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 following investment assets are included in the Companies' consolidated balance sheets at December 31, 2016 and 2015:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015		2016		2015
CET Gas investment in Stagecoach Gas Services, LLC (a)	$992		$—		$—		$—
Con Edison Development equity method investments (b)	488	574		—		—
Supplemental retirement income plan assets (c)	273	243		246		221
Deferred income plan assets	60	55		60		55
CET Electric investment in New York Transco, LLC	51	3		—		—
CET Gas investment in Mountain Valley Pipeline, LLC	48	—		—		—
Other	9	9		9		10
Total investments	$1,921	$884		$315		$286

(a) See Note U.

(b) See Note Q.

(c) 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. Generally, O&R also defers such difference pursuant to its 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 tax liability, the Utilities have established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense. See Notes B and L. In 1993, the NYSPSC issued a Policy Statement approving accounting procedures consistent with accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. See Note L.

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

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)	2016	2015	2014
Con Edison	$24	$23	$22
CECONY	22	22	20

Reclassification

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

Earnings Per Common Share

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

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

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

	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2014
Net income	$1,245	$1,193	$1,092
Weighted average common shares outstanding – basic	300.4	293.0	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.5	1.4	1.1
Adjusted weighted average common shares outstanding – diluted	301.9	294.4	294.0
Net Income per common share – basic	$4.15	$4.07	$3.73
Net Income per common share – diluted	$4.12	$4.05	$3.71

The computation of diluted EPS for the year ended December 31, 2014 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, 2014 (a)	$(45)	$(11)
OCI before reclassifications, net of tax of $(3) for Con Edison	5	1
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(4) and $(1) for Con Edison and CECONY, respectively(a)(b)	6	1
Total OCI, net of taxes, at December 31, 2015	11	2
Accumulated OCI, net of taxes, at December 31, 2015 (a)	$(34)	$(9)
OCI before reclassifications, net of tax of $(1) for Con Edison and CECONY	2	1
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(3) and $(1) for Con Edison and CECONY, respectively(a)(b)	5	1
Total OCI, net of taxes, at December 31, 2016	7	2
Accumulated OCI, net of taxes, at December 31, 2016 (a)	$(27)	$(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 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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Regulatory Matters

12 Months Ended

Dec. 31, 2016

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 New Jersey Board of Public Utilities (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. 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.

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.

Rate base is, in general, the sum of the Utilities’ net plant and working capital less deferred taxes. 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 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 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(76.2) million (a) Yr. 2 – $124.0 million (a) Yr. 3 – None	Yr. 1 - $195 million (b) Yr. 2 - $155 million (b) Yr. 3 - $155 million (b)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 and 2 – $(37) million (c) Yr. 3 - $123 million (c)	Yr. 1 - $84 million Yr. 2 - $83 million Yr. 3 - $69 million
Other revenue sources	Retention of $90 million of annual transmission congestion revenues.	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
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred for customer benefit $146 million, $98 million and $101 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs (d)	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties (up to $400 million annually) if certain performance targets are not met. In 2014, the company recorded a $5 million negative revenue adjustment. In 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $376 million Yr. 2 - $383 million Yr. 3 - $395 million.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $57 million, $26 million and $68 million of net regulatory liabilities, respectively (e).	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)
Net utility plant reconciliations	Target levels reflected in rates were: Transmission and distribution: Yr. 1 – $16,869 million Yr. 2 – $17,401 million Yr. 3 – $17,929 million Storm hardening: Yr. 1 – $89 million; Yr. 2 – $177 million; Yr. 3 – $268 million Other: Yr. 1 – $2,034 million; Yr. 2 – $2,102 million; Yr. 3 – $2,069 million The company deferred $6 million and $17 million as a regulatory liability in 2014 and 2015, respectively. In 2016, $9 million was deferred as a regulatory asset.	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
Average rate base	Yr. 1 – $17,323 million Yr. 2 – $18,113 million Yr. 3 – $18,282 million	Yr. 1 - $18,902 million Yr. 2 - $19,530 million Yr. 3 - $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.05 percent Yr. 2 – 7.08 percent Yr. 3 – 6.91 percent	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	Yrs. 1 and 2 – 9.2 percent Yr. 3 – 9.0 percent	9.0 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.8 percent for Yrs. 1 and 2 and 9.6 percent for Yr. 3 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 $44.4 million and $6.5 million above the threshold for 2015 and 2016, respectively.	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.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.09 percent	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $30 million regulatory liability at December 31, 2015; this amount has been amortized to $0 at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's electric rate plan for January 2017 through December 2019. The electric base rate increases are 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 are being 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 ten-year period, including the overall pre-tax rate of return on such costs.

(c) Amounts reflect annual amortization of $107 million of the regulatory asset for deferred Superstorm Sandy and other major storm costs. The costs recoverable from customers were reduced by $4 million. The costs are no longer subject to NYSPSC staff review and the recovery of the costs is no longer subject to refund. In 2016, an additional $123 million of net regulatory liabilities were amortized to income.

(d) For transmission service provided pursuant to the open access transmission tariff of PJM Interconnection LLC (PJM), unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. Starting in January 2014, PJM submitted to the FERC a series of requests that substantially increase the charges for the transmission service. CECONY has challenged each of these requests. To date, FERC has rejected all but one of CECONY’s protests. In April 2016, CECONY notified PJM that it will not be exercising its option to continue the service beyond April 2017. CECONY is continuing to challenge FERC’s approval of the increased charges that are being incurred through the end of the current contract term. In June 2015 and May 2016, CECONY filed appeals of certain FERC decisions with the U.S. Court of Appeals.

(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 (5.0, 7.5 or 10.0 basis points, depending on the year).

(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 of 30 percent of the amount reflected in rates.

(g) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers.

CECONY – Gas
Effective period	January 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(54.6) million (a) Yr. 2 – $38.6 million (a) Yr. 3 – $56.8 million (a)	Yr. 1 - $(5) million (b) Yr. 2 - $92 million (b) Yr. 3 - $90 million (b)
Amortizations to income of net regulatory (assets) and liabilities	$4 million over three years	Yr. 1 - $39 million Yr. 2 - $37 million Yr. 3 - $36 million
Other revenue sources	Retention of revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. The company retained $70 million, $66 million and $65 million of such revenues in 2014, 2015 and 2016, respectively.	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.
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred $28 million, $54 million and $71 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $33 million in 2014, $44 million in 2015, and $56 million in 2016) if certain gas performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 - $68 million Yr. 2 - $75 million Yr. 3 - $83 million.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $38 million, $11 million, and $32 million of net regulatory liabilities, respectively. (c)	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(d)
Net utility plant reconciliations	Target levels reflected in rates were: Gas delivery Yr. 1 – $3,899 million; Yr. 2 – $4,258 million; Yr. 3 – $4,698 million Storm hardening: Yr. 1 – $3 million; Yr. 2 – $8 million; Yr. 3 – $30 million In 2015 $1 million was deferred as a regulatory liability. In 2014 and 2016 the company deferred an immaterial amount.	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
Average rate base	Yr. 1 – $3,521 million Yr. 2 – $3,863 million Yr. 3 – $4,236 million	Yr. 1 - $4,841 million Yr. 2 - $5,395 million Yr. 3 - $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.3 percent	9.0 percent
Earnings sharing	Most 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, 2015 and 2016, the company had no earnings above the threshold.	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.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $32 million regulatory liability at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's gas rate plan for January 2017 through December 2019. The gas base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(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) See footnotes (e), (f) and (g) 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
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 penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015 and 2016, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets and $8 million of net regulatory liabilities, 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.
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
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.
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.

O&R New York – Electric
Effective period	July 2012 – June 2015	November 2015 - October 2017
Base rate changes	Yr. 1 – $19.4 million Yr. 2 – $8.8 million Yr. 3 – $15.2 million	Yr. 1 – $9.3 million Yr. 2 – $8.8 million
Amortizations to income of net regulatory (assets) and liabilities	$(32.2) million over three years	Yr. 1 – $(8.5) million (a) Yr. 2 – $(9.4) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred for the customer’s benefit $2.6 million, $3.2 million and $(3.4) million, respectively.	In 2015 and 2016, the company deferred for the customer’s benefit an immaterial amount and $6.3 million as regulatory liabilities, respectively.
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential penalties (up to $3 million annually) if certain customer service and system reliability performance targets are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (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, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase/(decrease) to regulatory assets, respectively.	In 2015 and 2016, the company deferred $0.3 million and $7.4 million as net decreases to regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Yr. 1 – $678 million; Yr. 2- $704 million; Yr. 3 – $753 million The company increased its regulatory liability by $4.2 million in 2012. The company reduced its regulatory liability by $1.1 million and $2.3 million in 2013 and 2014, respectively.	Target levels reflected in rates are: Yr. 1 – $928 million (b) Yr. 2 – $970 million (b) The company increased/(reduced) its regulatory asset by $2.2 million and $(1.9) million in 2015 and 2016, respectively.
Average rate base	Yr. 1 – $671 million Yr. 2 – $708 million Yr. 3 – $759 million	Yr. 1 – $763 million Yr. 2 – $805 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.61 percent Yr. 2 – 7.65 percent Yr. 3 – 7.48 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent
Authorized return on common equity	Yr. 1 – 9.4 percent Yr. 2 – 9.5 percent Yr. 3 – 9.6 percent	9.0 percent
Earnings sharing	The company recorded a regulatory liability of $1 million for earnings above the sharing threshold under the rate plan as of December 31, 2014.	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 above the threshold for 2016.
Cost of long-term debt	Yr. 1 – 6.07 percent Yr. 2 – 6.07 percent Yr. 3 – 5.64 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a five 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.

(b) 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.

O&R New York – Gas
Effective period	November 2009 – December 2014	November 2015 – October 2018
Base rate changes	Yr. 1 – $9 million Yr. 2 – $9 million Yr. 3 – $4.6 million Yr. 3 – $4.3 million collected through a surcharge Yr. 4 – None Yr. 5 – None	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge
Amortization to income of net regulatory (assets) and liabilities	$(2) million over three years	Yr. 1 – $(1.7) million (a) Yr. 2 – $(2.1) million (a) Yr. 3 – $(2.5) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred $4.7 million, $0.7 million and $(0.1) million of regulatory liabilities, respectively.	In 2015 and 2016, the company deferred $0.8 million regulatory assets and $6.2 million of regulatory liabilities, respectively.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $1.4 million annually) if certain operations and customer service requirements are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $5.8 million in Yr. 3) if certain performance targets are not met. In 2015 and 2016, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $0.7 million, $8.3 million and $8.3 million as net regulatory assets, respectively.	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively.
Net utility plant reconciliations	The company deferred $0.7 million in 2012 as a regulatory asset and no deferrals were recorded for 2013 or 2014.	Target levels reflected in rates are: Yr. 1 – $492 million (b) Yr. 2 – $518 million (b) Yr. 3 – $546 million (b) No deferral was recorded for 2015 and an immaterial amount was recorded as a regulatory liability in 2016.
Average rate base	Yr. 1 – $280 million Yr. 2 – $296 million Yr. 3 – $309 million	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million
Weighted average cost of capital (after-tax)	8.49 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent
Authorized return on common equity	10.4 percent	9.0 percent
Earnings sharing	Earnings above an annual earnings threshold of 11.4 percent are to be applied to reduce regulatory assets. In 2012, 2013 and 2014, 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. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million above the threshold for 2016.
Cost of long-term debt	6.81 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) 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.

(b) 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.

RECO
Effective period	May 2010 – July 2014	August 2014 – July 2015 (a)
Base rate changes	Yr. 1 – $9.8 million	Yr. 1 – $13.0 million
Amortization to income of net regulatory (assets) and liabilities	$(3.9) million over four years and $(4.9) million of deferred storm costs over five years	$0.4 million over three years and $(25.6) million of deferred storm costs 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	$148.6 million	$172.2 million
Weighted average cost of capital (after-tax)	8.21 percent	7.83 percent
Authorized return on common equity	10.3 percent	9.75 percent
Cost of long-term debt	6.16 percent	5.89 percent
Common equity ratio	50 percent	50 percent

(a) In January 2016, the NJBPU approved RECO’s plan for a 3-year, $15.7 million electric system storm hardening capital program, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge until a new rate plan is approved that reflects the costs.

In February 2017, RECO, the staff of the NJBPU and other parties entered into a stipulation of settlement for a RECO electric rate plan for the period commencing March 2017. The stipulation is subject to NJBPU approval. The rate plan would provide for an electric rate increase of $1.7 million, reflecting a return on common equity of 9.6 percent and a common equity ratio of 49.7 percent, and for continuation of the provisions for recovery from customers of the cost of purchased power.

In January 2017, RECO filed a request with FERC for an increase to its annual transmission revenue requirement from $11.8 million to $19.7 million, effective April 2017. The filing reflects a return on common equity of 10.7 percent and a common equity ratio of 48 percent.

Other Regulatory Matters

In June 2014, the NYSPSC initiated a proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. New York State regulations require gas utilities to qualify and, except in certain circumstances, annually requalify workers that perform fusion to join plastic pipe. The NYSPSC directed the New York gas utilities to provide information in this proceeding about their compliance with the qualification and requalification requirements and related matters; their procedures for compliance with all gas safety regulations; and their annual chief executive officer certifications regarding these and other procedures. CECONY’s qualification and requalification procedures had not included certain required testing to evaluate specimen fuses. In addition, CECONY and O&R had not timely requalified certain workers that had been qualified under their respective procedures to perform fusion to join plastic pipe. CECONY and O&R have requalified their workers who perform plastic pipe fusions. In May 2015, the NYSPSC, which indicated that it would address enforcement at a later date, ordered CECONY, O&R and other gas utilities to perform risk assessment and remediation plans, additional leakage surveying and reporting; CECONY to hire an independent statistician to develop a risk assessment and remediation plan; and the gas utilities to implement certain new plastic fusion requirements. In December 2015, the NYSPSC staff informed O&R that the company had satisfactorily completed its risk assessment and remediation plan. CECONY is implementing the three-year risk assessment and remediation plan it submitted to the NYSPSC staff in October 2016.

In November 2015, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence proceedings to penalize the company for alleged violations of gas safety regulations identified by the NYSPSC staff in its investigation of a March 2014 explosion and fire and to review the prudence of the company's conduct associated with the incident. See "Manhattan Explosion and Fire" in Note H. In December 2015, the company responded that the NYSPSC should not institute the proceedings and disputed the alleged violations.

In February 2017, the NYSPSC approved a settlement agreement with CECONY related to the June 2014 plastic fusion proceeding and the November 2015 order to show cause. Pursuant to the settlement agreement, the company will not recover from customers $126 million of costs it incurred for gas emergency response activities in 2014, 2015 and 2016 in excess of amounts reflected in its gas rate plan for those years. At December 31, 2016, the company had not deferred any such incremental costs as a regulatory asset. In addition, the company will provide $27 million of future benefits to customers. At December 31, 2016, the Company had accrued a regulatory liability for these future benefits.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2016 and 2015 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$2,874	$3,876	$2,730	$3,697
Future income tax	2,439	2,350	2,325	2,232
Environmental remediation costs	823	904	711	800
Revenue taxes	295	253	280	240
Deferred storm costs	56	185	3	110
Deferred derivative losses	48	50	42	46
Unamortized loss on reacquired debt	43	50	41	48
Recoverable energy costs	42	16	38	15
Pension and other postretirement benefits deferrals	38	45	7	16
O&R property tax reconciliation	37	46	—	—
Surcharge for New York State assessment	28	44	26	40
Preferred stock redemption	25	26	25	26
Net electric deferrals	24	44	24	44
O&R transition bond charges	15	21	—	—
Workers’ compensation	13	11	13	11
Other	224	175	208	157
Regulatory assets – noncurrent	7,024	8,096	6,473	7,482
Deferred derivative losses	91	113	86	103
Recoverable energy costs	9	19	4	18
Regulatory assets – current	100	132	90	121
Total Regulatory Assets	$7,124	$8,228	$6,563	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$755	$676	$641	$570
Pension and other postretirement benefit deferrals	193	76	162	46
Property tax reconciliation	178	303	178	303
Net unbilled revenue deferrals	145	109	145	109
Prudence proceeding	95	99	95	99
Carrying charges on repair allowance and bonus depreciation	68	49	67	48
New York State income tax rate change	61	75	60	72
Unrecognized other postretirement costs	60	28	60	28
Variable-rate tax-exempt debt - cost rate reconciliation	55	70	48	60
Base rate change deferrals	40	128	40	128
Earnings sharing - electric, gas and steam	39	80	28	80
Net utility plant reconciliations	16	32	15	31
Property tax refunds	1	44	1	44
World Trade Center settlement proceeds	—	21	—	21
Other	199	187	172	150
Regulatory liabilities – noncurrent	1,905	1,977	1,712	1,789
Revenue decoupling mechanism	71	45	61	45
Refundable energy costs	29	64	5	33
Deferred derivative gains	28	6	24	6
Regulatory liabilities—current	128	115	90	84
Total Regulatory Liabilities	$2,033	$2,092	$1,802	$1,873

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.

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

Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Superstorm Sandy and other major storms that were deferred by the Utilities.

Net electric deferrals represent the remaining unamortized balance of certain regulatory assets and liabilities of CECONY that were combined effective April 1, 2010 and are being amortized to income through March 31, 2018.

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

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 $145 million and $109 million at December 31, 2016 and 2015, respectively, for the difference between the unbilled revenues and energy cost liabilities.

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.

At December 31, 2016, the significant terms of the electricity purchase agreements with non-utility generators were as follows:

Facility	Equity Owner	Plant Output (MW)	Contracted Output (MW)	Contract Start Date	Contract Term (Years)
Brooklyn Navy Yard	Brooklyn Navy Yard Cogeneration Partners, LP	322	293	November 1996	40
Linden Cogeneration	Cogen Technologies Linden Venture, LP	974	630	May 1992	25
Indian Point	Entergy Nuclear Power Marketing, LLC	2,150	500	August 2001	16

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 contracts are estimated to be as follows:

(Millions of Dollars)	2017	2018	2019	2020	2021	All Years Thereafter
Con Edison	$178	$125	$120	$76	$54	$710
CECONY	178	125	119	75	54	710

For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the agreements for capacity, energy and other fixed payments in 2016, 2015 and 2014 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
Linden Cogeneration	$304	$323	$381
Indian Point	203	226	247
Astoria Energy (a)	50	178	230
Astoria Generating Company	16	—	—
Brooklyn Navy Yard	119	113	133
Indeck Corinth (b)	—	25	80
Selkirk (c)	—	—	144
Independence (c)	—	—	97
Total	$692	$865	$1,312

(a) Contract term ended in 2016.

(b) Contract term ended in 2015.

(c) Contract term ended in 2014

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Capitalization

12 Months Ended

Dec. 31, 2016

Debt Disclosure [Abstract]

Capitalization

Capitalization

Common Stock

At December 31, 2016 and 2015, Con Edison owned all of the issued and outstanding shares of common stock of the Utilities, the Clean Energy Businesses and Con Edison Transmission. CECONY owns 21,976,200 shares of Con Edison stock, which it purchased prior to 2001 in connection with Con Edison’s stock repurchase plan. CECONY presents in the financial statements the cost of the Con Edison stock it owns as a reduction of common shareholder’s equity.

Capitalization of Con Edison

The outstanding capitalization for each of the Companies is shown on its Consolidated Statement of Capitalization, and for Con Edison includes outstanding 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. 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 2017-2021 is as follows:

(Millions of Dollars)	Con Edison	CECONY
2017	$39		$—
2018	1,688	1,200
2019	574	475
2020	388	350
2021	540	—

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, 2016 and 2015 are:

(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,774	$16,093	$12,745	$13,856
CECONY	$12,073	$13,268	$11,437	$12,427

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $15,457 million and $636 million of the fair value of long-term debt at December 31, 2016 are classified as Level 2 and Level 3, respectively. For CECONY, $12,632 million and $636 million of the fair value of long-term debt at December 31, 2016 are classified as Level 2 and Level 3, respectively (see Note P). The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.

At December 31, 2016 and 2015, long-term debt of Con Edison included $845 million and $339 million, respectively, of non-recourse debt secured by the pledge of the applicable renewable energy production projects of the Clean Energy Businesses. At December 31, 2016 and 2015, long-term debt of Con Edison included $11 million and $15 million, respectively, of Transition Bonds issued in 2004 by O&R’s New Jersey utility subsidiary through a special purpose entity.

Significant Debt Covenants

The significant debt covenants under the financing arrangements for the Companies' debentures and Con Edison's notes and term loan include obligations to pay principal and interest when due and covenants not to consolidate with or merge into any other corporation 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 capital to exceed certain amounts (0.675 to 1 for the notes and 0.65 to 1 for the term loan) and include cross default provisions with respect to other indebtedness of the company or its subsidiaries (material subsidiaries, in the case of the notes) having a then outstanding principal balance in excess of certain amounts ($100 million for the notes and $150 million for the term loan). 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, 2016.

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, 2016

Debt Disclosure [Abstract]

Short-Term Borrowing

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 expires in December 2021. There is a maximum of $2,250 million of credit available. 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, 2016, Con Edison had $1,054 million of commercial paper outstanding, of which $600 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2016 was 1.0 percent for both Con Edison and CECONY. At December 31, 2015, Con Edison had $1,529 million of commercial paper outstanding of which $1,033 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2015 was 0.7 percent for both Con Edison and CECONY. At December 31, 2016 and 2015, no loans were outstanding under the Credit Agreement and $2 million (including $2 million for CECONY) and $15 million of letters of credit were outstanding under the Credit Agreement, respectively.

The banks’ commitments under the Credit Agreement are subject to certain conditions, including that there be no event of default. The commitments are not subject to maintenance of credit rating levels or the absence of a material adverse change. Upon a change of control of, or upon an event of default by one of the Companies, the banks may terminate their commitments with respect to that company, declare any amounts owed by that company under the Credit Agreement immediately due and payable and require that company to provide cash collateral relating to the letters of credit issued for it under the Credit Agreement. Events of default include the exceeding at any time of a ratio of consolidated debt to consolidated total capital of 0.65 to 1 (at December 31, 2016 this ratio was 0.51 to 1 for Con Edison and 0.52 to 1 for CECONY); having liens on its assets in an aggregate amount exceeding five percent of its consolidated total capital, subject to certain exceptions; and the failure, following any applicable notice period, to meet certain other customary covenants. Interest and fees charged for the revolving credit facilities and any loans made or letters of credit issued under the Credit Agreement reflect the Companies’ respective credit ratings. The Companies were in compliance with their covenants at December 31, 2016.

See Note S for information about short-term borrowing between related parties.

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Pension Benefits

12 Months Ended

Dec. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Pension Benefits

Pension Benefits

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

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit costs for 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Service cost – including administrative expenses	$275	$297	$227	$258	$279	$211
Interest cost on projected benefit obligation	596	575	572	559	538	536
Expected return on plan assets	(947)	(886)	(832)	(898)	(840)	(789)
Recognition of net actuarial loss	596	775	618	565	734	586
Recognition of prior service costs	4	4	4	2	2	2
NET PERIODIC BENEFIT COST	$524	$765	$589	$486	$713	$546
Amortization of regulatory asset (a)	—	1	2	—	1	2
TOTAL PERIODIC BENEFIT COST	$524	$766	$591	$486	$714	$548
Cost capitalized	(214)	(301)	(225)	(203)	(285)	(212)
Reconciliation to rate level	54	(74)	118	58	(74)	108
Cost charged to operating expenses	$364	$391	$484	$341	$355	$444

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

Funded Status

The funded status at December 31, 2016, 2015 and 2014 was as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$14,377	$15,081	$12,197	$13,482	$14,137	$11,429
Service cost – excluding administrative expenses	271	293	221	254	274	206
Interest cost on projected benefit obligation	596	575	572	559	538	536
Net actuarial (gain)/loss	(302)	(996)	2,641	(282)	(931)	2,484
Plan amendments	(256)	—	6	(259)	—	—
Benefits paid	(591)	(576)	(556)	(551)	(536)	(518)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$14,095	$14,377	$15,081	$13,203	$13,482	$14,137
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$11,759	$11,495	$10,755	$11,141	$10,897	$10,197
Actual return on plan assets	829	126	752	787	118	715
Employer contributions	508	750	578	469	697	535
Benefits paid	(591)	(576)	(556)	(551)	(536)	(518)
Administrative expenses	(33)	(36)	(34)	(31)	(35)	(32)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$12,472	$11,759	$11,495	$11,815	$11,141	$10,897
FUNDED STATUS	$(1,623)	$(2,618)	$(3,586)	$(1,388)	$(2,341)	$(3,240)
Unrecognized net loss	$3,157	$3,909	$4,888	$2,995	$3,704	$4,616
Unrecognized prior service costs	(244)	16	20	(258)	3	4
Accumulated benefit obligation	12,655	12,909	13,454	11,806	12,055	12,553

The decrease in the pension plan’s projected benefit obligation was the primary cause of the decreased pension liability at Con Edison and CECONY of $995 million and $953 million, respectively, compared with December 31, 2015. For Con Edison, this decrease in pension liability corresponds with a decrease to regulatory assets of $1,002 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 $5 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 the Clean Energy Businesses and RECO.

For CECONY, the decrease in pension liability corresponds with a decrease to regulatory assets of $967 million for unrecognized net losses and unrecognized prior service costs consistent with the accounting rules for regulated operations, a credit to OCI of $1 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 the Clean Energy Businesses.

A portion of the unrecognized net loss and prior service cost for the pension plan, equal to $579 million and $(16) million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $548 million and $(18) million, respectively, for CECONY.

At December 31, 2016 and 2015, Con Edison’s investments include $273 million and $243 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $246 million and $221 million, respectively. See Note P. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $303 million and $268 million as of December 31, 2016 and $285 million and $249 million as of December 31, 2015, respectively.

Assumptions

The actuarial assumptions were as follows:

	2016		2015		2014
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate	4.25	%	4.25	%	3.90	%
Rate of compensation increase
CECONY	4.25	%	4.25	%	4.25	%
O&R	4.00	%	4.00	%	4.00	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.25	%	3.90	%	4.80	%
Expected return on plan assets	7.80	%	7.80	%	8.00	%
Rate of compensation increase
CECONY	4.25	%	4.25	%	4.35	%
O&R	4.00	%	4.00	%	4.25	%

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

Discount Rate Assumption

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

Expected Benefit Payments

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

(Millions of Dollars)	2017	2018	2019	2020	2021	2022-2026
Con Edison	$702	$719	$730	$745	$758	$3,990
CECONY	653	670	679	693	705	3,716

Expected Contributions

Based on estimates as of December 31, 2016, the Companies expect to make contributions to the pension plans during 2017 of $423 million (of which $388 million is to be contributed 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 2016, 2015 and 2014, and the target allocation for 2017 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2017	2016		2015		2014
Equity Securities	52% - 64%	58	%	57	%	58	%
Debt Securities	28% - 38%	33	%	33	%	32	%
Real Estate	7% - 11%	9	%	10	%	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 2017 reflects the results of such a study conducted in 2016.

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.

In May 2015, the FASB issued ASU 2015-07, Fair Value Measurements (Topic 820):Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or its equivalent), which exempts investments measured using net asset value (NAV) practical expedient in ASC 820, Fair Value Measurement, from categorization within the fair value hierarchy. The guidance requires retrospective application and is effective for public business entities for fiscal years, and interim periods within those years, beginning after December 15, 2015. Accordingly, the amendment was retrospectively applied, resulting in the reclassification of real estate funds, private equity and hedge fund investments from Level III assets on the fair value hierarchy to investments measured at net asset value.

Assets measured at fair value on a recurring basis are summarized below as defined by the accounting rules for fair value measurements (see Note P).

The fair values of the pension plan assets at December 31, 2016 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2		Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,466		$—	$3,466
International Equity (b)	3,187	371		3,558
U.S. Government Issued Debt (c)	—	1,337		1,337
Corporate Bonds Debt (d)	—	2,140		2,140
Structured Assets Debt (e)	—	1		1
Other Fixed Income Debt (f)	—	200		200
Cash and Cash Equivalents (g)	147	389		536
Futures (h)	296	68		364
Total investments within the fair value hierarchy	$7,096	$4,506		$11,602
Investments measured at NAV per share (n)
Private Equity (i)				247
Real Estate (j)				1,139
Hedge Funds (k)				229
Total investments valued using NAV per share				$1,615
Funds for retiree health benefits (l)	(165)	(105)		(270)
Funds for retiree health benefits measured at NAV per share (l)(n)				(37)
Total funds for retiree health benefits				$(307)
Investments (excluding funds for retiree health benefits)	$6,931	$4,401		$12,910
Pending activities (m)				(438)
Total fair value of plan net assets				$12,472

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

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

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

(k) Hedge Funds are within a commingled structure which invests in various hedge fund managers who can invest in all financial instruments.

(l) 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.

(m) 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.

(n) In accordance with ASU 2015-07, 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, 2015 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2		Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,106		$—	$3,106
International Equity (b)	2,874	346		3,220
U.S. Government Issued Debt (c)	—	2,222		2,222
Corporate Bonds Debt (d)	—	1,356		1,356
Structured Assets Debt (e)	—	1		1
Other Fixed Income Debt (f)	—	170		170
Cash and Cash Equivalents (g)	115	414		529
Futures (h)	161	132		293
Total investments within the fair value hierarchy	$6,256	$4,641		$10,897
Investments measured at NAV per share (n)
Private Equity (i)				170
Real Estate (j)				1,248
Hedge Funds (k)				233
Total investments valued using NAV per share				$1,651
Funds for retiree health benefits (l)	(162)	(120)		(282)
Funds for retiree health benefits measured at NAV per share (l)(n)				(43)
Total funds for retiree health benefits				$(325)
Investments (excluding funds for retiree health benefits)	$6,094	$4,521		$12,223
Pending activities (m)				(464)
Total fair value of plan net assets				$11,759

(a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2016 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)	2016	2015	2014
Con Edison	$36	$34	$32
CECONY	32	29	27

Mortality Table Revision

The Companies adopted revised mortality tables effective December 31, 2014 in the measurement of its pension and other postretirement benefit plan obligations, accounting costs and required contribution amounts. The revised tables reflect the RP-2014 mortality tables published by the Society of Actuaries in October 2014, as adjusted based on the actual experience of the Companies. The new tables incorporate substantial life expectancy improvements relative to the last tables published in 2000 (RP-2000). As a result of the adoption, Con Edison recognized an increase in its pension benefit obligation of approximately $800 million as of December 31, 2014. The Companies, under their current New York rate plans, defer as a regulatory asset or liability, as the case may be, the differences between the actual level of expenses for pension and other postretirement benefits and amounts for those expenses reflected in rates.

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Other Postretirement Benefits

12 Months Ended

Dec. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Other Postretirement Benefits

Other Postretirement Benefits

The Utilities 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 are eligible to receive benefits under these programs.

Total Periodic Benefit Cost

The components of the Companies’ total periodic postretirement benefit costs for 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Service cost	$18	$20	$19	$13	$15	$15
Interest cost on accumulated other postretirement benefit obligation	48	51	60	40	43	52
Expected return on plan assets	(77)	(78)	(77)	(67)	(68)	(68)
Recognition of net actuarial loss	5	31	57	3	28	51
Recognition of prior service cost	(20)	(20)	(19)	(14)	(14)	(15)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST	$(26)	$4	$40	$(25)	$4	$35
Cost capitalized	11	(2)	(15)	10	(2)	(14)
Reconciliation to rate level	22	14	10	22	6	2
Cost charged to operating expenses	$7	$16	$35	$7	$8	$23

Funded Status

The funded status of the programs at December 31, 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$1,287	$1,411	$1,395	$1,093	$1,203	$1,198
Service cost	18	20	19	13	15	15
Interest cost on accumulated postretirement benefit obligation	48	51	60	40	43	52
Amendments	—	—	(12)	—	—	—
Net actuarial loss/(gain)	(57)	(103)	47	(52)	(85)	28
Benefits paid and administrative expenses	(134)	(127)	(134)	(122)	(117)	(125)
Participant contributions	36	35	36	35	34	35
BENEFIT OBLIGATION AT END OF YEAR	$1,198	$1,287	$1,411	$1,007	$1,093	$1,203
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$994	$1,084	$1,113	$870	$950	$977
Actual return on plan assets	60	(6)	59	52	(4)	54
Employer contributions	7	6	7	7	6	7
EGWP payments	35	28	12	33	26	11
Participant contributions	36	35	36	35	34	35
Benefits paid	(157)	(153)	(143)	(146)	(142)	(134)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$975	$994	$1,084	$851	$870	$950
FUNDED STATUS	$(223)	$(293)	$(327)	$(156)	$(223)	$(253)
Unrecognized net loss/(gain)	$(24)	$28	$78	$(42)	$4	$45
Unrecognized prior service costs	(31)	(51)	(71)	(18)	(32)	(46)

The decrease in the other postretirement benefit plan obligation was the primary cause of the decreased liability for other postretirement benefits at Con Edison and CECONY of $70 million and $67 million, respectively, compared with December 31, 2015. For Con Edison, this decreased liability corresponds with an increase to regulatory liabilities of $32 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 a debit to OCI of $1 million (net of taxes) for the unrecognized prior service costs associated with the Clean Energy Businesses and RECO.

For CECONY, the decrease in liability corresponds with an increase to regulatory liabilities of $32 million for unrecognized net losses and unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, and a credit to OCI of $1 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 the Clean Energy Businesses.

A portion of the unrecognized net losses and prior service costs for the other postretirement benefits, equal to $4 million and $(17) million, respectively, will be recognized from accumulated OCI and the regulatory asset into net periodic benefit cost over the next year for Con Edison. Included in these amounts are $1 million and $(11) million, respectively, for CECONY.

Assumptions

The actuarial assumptions were as follows:

	2016		2015		2014
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY	4.00	%	4.05	%	3.75	%
O&R	4.20	%	4.20	%	3.85	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate
CECONY	4.05	%	3.75	%	4.50	%
O&R	4.20	%	3.85	%	4.75	%
Expected Return on Plan Assets	7.00	%	7.75	%	7.75	%

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 year ended December 31, 2016 was 6.00 percent, which is 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, 2016 was 5.80 percent, which is assumed to decrease gradually to 4.50 percent by 2024 and remain at that level thereafter.

A one-percentage point change in the assumed health care cost trend rate would have the following effects at December 31, 2016:

	Con Edison		CECONY
	1-Percentage-Point
(Millions of Dollars)	Increase	Decrease	Increase	Decrease
Effect on accumulated other postretirement benefit obligation	$(4)	$26	$(24)	$41
Effect on service cost and interest cost components for 2016	1	—	(1)	1

Expected Benefit Payments

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

(Millions of Dollars)	2017	2018	2019	2020	2021	2022-2026
Con Edison	$86	$85	$83	$80	$78	$375
CECONY	77	75	73	70	68	322

Expected Contributions

Based on estimates as of December 31, 2016, Con Edison and CECONY expect to make a contribution of $14 million (of which $10 million is to be contributed by CECONY) to the other postretirement benefit plans in 2017. 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 2016, 2015 and 2014, and the target allocation for 2017 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2017	2016		2015		2014
Equity Securities	57%-73%	60	%	59	%	59	%
Debt Securities	26%-44%	40	%	41	%	41	%
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 plan assets at December 31, 2016 by asset category as defined by the accounting rules for fair value measurements (see Note P) are as follows:

(Millions of Dollars)	Level 1		Level 2	Total
Equity (a)		$—	$391	$391
Other Fixed Income Debt (b)	—		250	250
Cash and Cash Equivalents (c)	—		13	13
Total investments		$—	$654	$654
Funds for retiree health benefits (d)	165		105	270
Investments (including funds for retiree health benefits)	$165		$759	$924
Funds for retiree health benefits measured at net asset value (d)(e)				37
Pending activities (f)				14
Total fair value of plan net assets				$975

(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 Barclays Capital Aggregate 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, 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. See Note E.

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

The fair values of the plan assets at December 31, 2015 by asset category (see Note P) are as follows:

(Millions of Dollars)	Level 1		Level 2	Total
Equity (a)		$—	$393	$393
Other Fixed Income Debt (b)	—		260	260
Cash and Cash Equivalents (c)	—		7	7
Total investments		$—	$660	$660
Funds for retiree health benefits (d)	162		120	282
Investments (including funds for retiree health benefits)	$162		$780	$942
Funds for retiree health benefits measured at net asset value (d)(e)				43
Pending activities (f)				9
Total fair value of plan net assets				$994

(a) - (f) Reference is made to footnotes (a) through (f) in the above table of other postretirement benefit plan assets at December 31, 2016 by asset category.

Mortality Table Revision

The Companies adopted revised mortality tables effective December 31, 2014 in the measurement of its pension and other postretirement benefit plan obligations, accounting costs, and required contribution amounts as discussed in Note E. As a result of the adoption, Con Edison recognized an increase of less than $10 million in its other postretirement benefits obligation as of December 31, 2014. The Companies, under their current New York rate plans, defer as a regulatory asset or liability, as the case may be, the differences between the actual level of expenses for pension and other postretirement benefits and amounts for those expenses reflected in rates.

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Environmental Matters

12 Months Ended

Dec. 31, 2016

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, 2016 and 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$664	$679	$567	$579
Other Superfund Sites	89	86	88	86
Total	$753	$765	$655	$665
Regulatory assets	$823	$904	$711	$800

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 and insurance recoveries received related to Superfund Sites at December 31, 2016 and 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$34	$37	$21	$34
Insurance recoveries received (a)	1	—	1	—

(a) Reduced amount deferred for recovery from customers

Con Edison and CECONY estimate that in 2017 they will incur costs for remediation of approximately $55 million and $47 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 2016, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $2.8 billion and $2.6 billion, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different.

Asbestos Proceedings

Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, which are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At December 31, 2016, 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, 2016 and 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$88	$86	$83	$81
Regulatory assets – workers’ compensation	$13	$11	$13	$11

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Other Material Contingencies

12 Months Ended

Dec. 31, 2016

Commitments and Contingencies Disclosure [Abstract]

Other Material Contingencies

Other Material Contingencies

Manhattan Steam Main Rupture

In July 2007, a CECONY steam main located in midtown Manhattan ruptured. It has been reported that one person died and others were injured as a result of the incident. Several buildings in the area were damaged. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of several buildings and streets for various periods. Approximately sixty suits are pending against the company seeking generally unspecified compensatory and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs to satisfy its liability to others in connection with the suits. In the company’s estimation, there is not a reasonable possibility that an exposure to loss exists for the suits that is materially in excess of the estimated liability accrued. At December 31, 2016, the company has accrued its estimated liability for the suits of $25 million and an insurance receivable of $25 million.

Manhattan Explosion and Fire

On March 12, 2014, two multi-use five-story tall buildings located on Park Avenue between 116th and 117th Street 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 (which also conducted an investigation). 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. Approximately seventy suits are pending against the company seeking generally unspecified damages and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have for damages in connection with the incident. The company is unable to estimate the amount or range of its possible loss for damages related to the incident. At December 31, 2016, the company had not accrued a liability for damages related to the incident.

Other Contingencies

See “Other Regulatory Matters” in Note B and "Uncertain Tax Positions" in Note L.

Guarantees

Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled $2,370 million and $2,856 million at December 31, 2016 and 2015, respectively.

A summary, by type and term, of Con Edison’s total guarantees at December 31, 2016 is as follows:

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$435	$613		$—	$1,048
Energy transactions	603	35	98		736
Renewable electric production projects	439	—	19		458
Other	128	—	—		128
Total	$1,605	$648	$117		$2,370

Con Edison Transmission – Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric acquired a 45.7 percent interest in NY Transco when it was formed in 2014. In May 2016, the transmission owners transferred certain projects to NY Transco, as to which CET Electric made its required contributions. The other projects that were proposed when NY Transco was formed remain subject to certain authorizations from the NYSPSC, the FERC and, as applicable, other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of CET Electric's contributions for these other projects as calculated based on the assumptions that the projects are completed at 175 percent of their estimated costs and NY Transco does not use any debt financing for the projects. Guarantee term shown is assumed as the timing of the contributions is not certain. Also included within the table above is a guarantee for $25 million from Con Edison on behalf of CET Gas in relation to a proposed gas transmission project in West Virginia and Virginia. See Note U.

Energy Transactions — Con Edison guarantees payments on behalf of the Clean Energy Businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet. Guarantee amounts shown above include $42 million of guarantees or other credit support provided by Con Edison on behalf of Con Edison Solutions that may continue in effect during the period in which Con Edison Solutions provides transition services in connection with the retail electric supply business it sold in September 2016. See Note U. As part of the sale agreement, the purchaser has agreed to pay Con Edison Solutions for draws on such guarantees or other credit support.

Renewable Electric Production Projects – Con Edison, Con Edison Development and Con Edison Solutions guarantee payments associated with the investment in solar and wind energy facilities on behalf of their wholly-owned subsidiaries.

Other – Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with operation of solar energy facilities and energy service projects of Con Edison Development and Con Edison Solutions, respectively. Other guarantees also includes Con Edison's guarantee (subject to a $53 million maximum amount) of certain obligations of Con Edison Solutions under its agreement to sell its retail electric supply business. See Note U. In addition, Con Edison issued a guarantee estimated at $5 million to the Public Utility Commission of Texas covering obligations of Con Edison Solutions as a retail electric provider. As part of the sale agreement for the retail electric supply business discussed above, the purchaser has agreed to pay Con Edison Solutions for draws on the guarantee to the Public Utility Commission of Texas.

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Electricity Purchase Agreements

12 Months Ended

Dec. 31, 2016

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 New Jersey Board of Public Utilities (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. 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.

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.

Rate base is, in general, the sum of the Utilities’ net plant and working capital less deferred taxes. 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 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 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(76.2) million (a) Yr. 2 – $124.0 million (a) Yr. 3 – None	Yr. 1 - $195 million (b) Yr. 2 - $155 million (b) Yr. 3 - $155 million (b)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 and 2 – $(37) million (c) Yr. 3 - $123 million (c)	Yr. 1 - $84 million Yr. 2 - $83 million Yr. 3 - $69 million
Other revenue sources	Retention of $90 million of annual transmission congestion revenues.	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
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred for customer benefit $146 million, $98 million and $101 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs (d)	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties (up to $400 million annually) if certain performance targets are not met. In 2014, the company recorded a $5 million negative revenue adjustment. In 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $376 million Yr. 2 - $383 million Yr. 3 - $395 million.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $57 million, $26 million and $68 million of net regulatory liabilities, respectively (e).	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)
Net utility plant reconciliations	Target levels reflected in rates were: Transmission and distribution: Yr. 1 – $16,869 million Yr. 2 – $17,401 million Yr. 3 – $17,929 million Storm hardening: Yr. 1 – $89 million; Yr. 2 – $177 million; Yr. 3 – $268 million Other: Yr. 1 – $2,034 million; Yr. 2 – $2,102 million; Yr. 3 – $2,069 million The company deferred $6 million and $17 million as a regulatory liability in 2014 and 2015, respectively. In 2016, $9 million was deferred as a regulatory asset.	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
Average rate base	Yr. 1 – $17,323 million Yr. 2 – $18,113 million Yr. 3 – $18,282 million	Yr. 1 - $18,902 million Yr. 2 - $19,530 million Yr. 3 - $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.05 percent Yr. 2 – 7.08 percent Yr. 3 – 6.91 percent	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	Yrs. 1 and 2 – 9.2 percent Yr. 3 – 9.0 percent	9.0 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.8 percent for Yrs. 1 and 2 and 9.6 percent for Yr. 3 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 $44.4 million and $6.5 million above the threshold for 2015 and 2016, respectively.	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.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.09 percent	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $30 million regulatory liability at December 31, 2015; this amount has been amortized to $0 at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's electric rate plan for January 2017 through December 2019. The electric base rate increases are 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 are being 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 ten-year period, including the overall pre-tax rate of return on such costs.

(c) Amounts reflect annual amortization of $107 million of the regulatory asset for deferred Superstorm Sandy and other major storm costs. The costs recoverable from customers were reduced by $4 million. The costs are no longer subject to NYSPSC staff review and the recovery of the costs is no longer subject to refund. In 2016, an additional $123 million of net regulatory liabilities were amortized to income.

(d) For transmission service provided pursuant to the open access transmission tariff of PJM Interconnection LLC (PJM), unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. Starting in January 2014, PJM submitted to the FERC a series of requests that substantially increase the charges for the transmission service. CECONY has challenged each of these requests. To date, FERC has rejected all but one of CECONY’s protests. In April 2016, CECONY notified PJM that it will not be exercising its option to continue the service beyond April 2017. CECONY is continuing to challenge FERC’s approval of the increased charges that are being incurred through the end of the current contract term. In June 2015 and May 2016, CECONY filed appeals of certain FERC decisions with the U.S. Court of Appeals.

(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 (5.0, 7.5 or 10.0 basis points, depending on the year).

(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 of 30 percent of the amount reflected in rates.

(g) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers.

CECONY – Gas
Effective period	January 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(54.6) million (a) Yr. 2 – $38.6 million (a) Yr. 3 – $56.8 million (a)	Yr. 1 - $(5) million (b) Yr. 2 - $92 million (b) Yr. 3 - $90 million (b)
Amortizations to income of net regulatory (assets) and liabilities	$4 million over three years	Yr. 1 - $39 million Yr. 2 - $37 million Yr. 3 - $36 million
Other revenue sources	Retention of revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. The company retained $70 million, $66 million and $65 million of such revenues in 2014, 2015 and 2016, respectively.	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.
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred $28 million, $54 million and $71 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $33 million in 2014, $44 million in 2015, and $56 million in 2016) if certain gas performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 - $68 million Yr. 2 - $75 million Yr. 3 - $83 million.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $38 million, $11 million, and $32 million of net regulatory liabilities, respectively. (c)	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(d)
Net utility plant reconciliations	Target levels reflected in rates were: Gas delivery Yr. 1 – $3,899 million; Yr. 2 – $4,258 million; Yr. 3 – $4,698 million Storm hardening: Yr. 1 – $3 million; Yr. 2 – $8 million; Yr. 3 – $30 million In 2015 $1 million was deferred as a regulatory liability. In 2014 and 2016 the company deferred an immaterial amount.	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
Average rate base	Yr. 1 – $3,521 million Yr. 2 – $3,863 million Yr. 3 – $4,236 million	Yr. 1 - $4,841 million Yr. 2 - $5,395 million Yr. 3 - $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.3 percent	9.0 percent
Earnings sharing	Most 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, 2015 and 2016, the company had no earnings above the threshold.	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.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $32 million regulatory liability at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's gas rate plan for January 2017 through December 2019. The gas base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(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) See footnotes (e), (f) and (g) 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
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 penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015 and 2016, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets and $8 million of net regulatory liabilities, 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.
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
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.
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.

O&R New York – Electric
Effective period	July 2012 – June 2015	November 2015 - October 2017
Base rate changes	Yr. 1 – $19.4 million Yr. 2 – $8.8 million Yr. 3 – $15.2 million	Yr. 1 – $9.3 million Yr. 2 – $8.8 million
Amortizations to income of net regulatory (assets) and liabilities	$(32.2) million over three years	Yr. 1 – $(8.5) million (a) Yr. 2 – $(9.4) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred for the customer’s benefit $2.6 million, $3.2 million and $(3.4) million, respectively.	In 2015 and 2016, the company deferred for the customer’s benefit an immaterial amount and $6.3 million as regulatory liabilities, respectively.
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential penalties (up to $3 million annually) if certain customer service and system reliability performance targets are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (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, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase/(decrease) to regulatory assets, respectively.	In 2015 and 2016, the company deferred $0.3 million and $7.4 million as net decreases to regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Yr. 1 – $678 million; Yr. 2- $704 million; Yr. 3 – $753 million The company increased its regulatory liability by $4.2 million in 2012. The company reduced its regulatory liability by $1.1 million and $2.3 million in 2013 and 2014, respectively.	Target levels reflected in rates are: Yr. 1 – $928 million (b) Yr. 2 – $970 million (b) The company increased/(reduced) its regulatory asset by $2.2 million and $(1.9) million in 2015 and 2016, respectively.
Average rate base	Yr. 1 – $671 million Yr. 2 – $708 million Yr. 3 – $759 million	Yr. 1 – $763 million Yr. 2 – $805 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.61 percent Yr. 2 – 7.65 percent Yr. 3 – 7.48 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent
Authorized return on common equity	Yr. 1 – 9.4 percent Yr. 2 – 9.5 percent Yr. 3 – 9.6 percent	9.0 percent
Earnings sharing	The company recorded a regulatory liability of $1 million for earnings above the sharing threshold under the rate plan as of December 31, 2014.	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 above the threshold for 2016.
Cost of long-term debt	Yr. 1 – 6.07 percent Yr. 2 – 6.07 percent Yr. 3 – 5.64 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a five 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.

(b) 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.

O&R New York – Gas
Effective period	November 2009 – December 2014	November 2015 – October 2018
Base rate changes	Yr. 1 – $9 million Yr. 2 – $9 million Yr. 3 – $4.6 million Yr. 3 – $4.3 million collected through a surcharge Yr. 4 – None Yr. 5 – None	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge
Amortization to income of net regulatory (assets) and liabilities	$(2) million over three years	Yr. 1 – $(1.7) million (a) Yr. 2 – $(2.1) million (a) Yr. 3 – $(2.5) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred $4.7 million, $0.7 million and $(0.1) million of regulatory liabilities, respectively.	In 2015 and 2016, the company deferred $0.8 million regulatory assets and $6.2 million of regulatory liabilities, respectively.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $1.4 million annually) if certain operations and customer service requirements are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $5.8 million in Yr. 3) if certain performance targets are not met. In 2015 and 2016, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $0.7 million, $8.3 million and $8.3 million as net regulatory assets, respectively.	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively.
Net utility plant reconciliations	The company deferred $0.7 million in 2012 as a regulatory asset and no deferrals were recorded for 2013 or 2014.	Target levels reflected in rates are: Yr. 1 – $492 million (b) Yr. 2 – $518 million (b) Yr. 3 – $546 million (b) No deferral was recorded for 2015 and an immaterial amount was recorded as a regulatory liability in 2016.
Average rate base	Yr. 1 – $280 million Yr. 2 – $296 million Yr. 3 – $309 million	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million
Weighted average cost of capital (after-tax)	8.49 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent
Authorized return on common equity	10.4 percent	9.0 percent
Earnings sharing	Earnings above an annual earnings threshold of 11.4 percent are to be applied to reduce regulatory assets. In 2012, 2013 and 2014, 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. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million above the threshold for 2016.
Cost of long-term debt	6.81 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) 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.

(b) 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.

RECO
Effective period	May 2010 – July 2014	August 2014 – July 2015 (a)
Base rate changes	Yr. 1 – $9.8 million	Yr. 1 – $13.0 million
Amortization to income of net regulatory (assets) and liabilities	$(3.9) million over four years and $(4.9) million of deferred storm costs over five years	$0.4 million over three years and $(25.6) million of deferred storm costs 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	$148.6 million	$172.2 million
Weighted average cost of capital (after-tax)	8.21 percent	7.83 percent
Authorized return on common equity	10.3 percent	9.75 percent
Cost of long-term debt	6.16 percent	5.89 percent
Common equity ratio	50 percent	50 percent

(a) In January 2016, the NJBPU approved RECO’s plan for a 3-year, $15.7 million electric system storm hardening capital program, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge until a new rate plan is approved that reflects the costs.

In February 2017, RECO, the staff of the NJBPU and other parties entered into a stipulation of settlement for a RECO electric rate plan for the period commencing March 2017. The stipulation is subject to NJBPU approval. The rate plan would provide for an electric rate increase of $1.7 million, reflecting a return on common equity of 9.6 percent and a common equity ratio of 49.7 percent, and for continuation of the provisions for recovery from customers of the cost of purchased power.

In January 2017, RECO filed a request with FERC for an increase to its annual transmission revenue requirement from $11.8 million to $19.7 million, effective April 2017. The filing reflects a return on common equity of 10.7 percent and a common equity ratio of 48 percent.

Other Regulatory Matters

In June 2014, the NYSPSC initiated a proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. New York State regulations require gas utilities to qualify and, except in certain circumstances, annually requalify workers that perform fusion to join plastic pipe. The NYSPSC directed the New York gas utilities to provide information in this proceeding about their compliance with the qualification and requalification requirements and related matters; their procedures for compliance with all gas safety regulations; and their annual chief executive officer certifications regarding these and other procedures. CECONY’s qualification and requalification procedures had not included certain required testing to evaluate specimen fuses. In addition, CECONY and O&R had not timely requalified certain workers that had been qualified under their respective procedures to perform fusion to join plastic pipe. CECONY and O&R have requalified their workers who perform plastic pipe fusions. In May 2015, the NYSPSC, which indicated that it would address enforcement at a later date, ordered CECONY, O&R and other gas utilities to perform risk assessment and remediation plans, additional leakage surveying and reporting; CECONY to hire an independent statistician to develop a risk assessment and remediation plan; and the gas utilities to implement certain new plastic fusion requirements. In December 2015, the NYSPSC staff informed O&R that the company had satisfactorily completed its risk assessment and remediation plan. CECONY is implementing the three-year risk assessment and remediation plan it submitted to the NYSPSC staff in October 2016.

In November 2015, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence proceedings to penalize the company for alleged violations of gas safety regulations identified by the NYSPSC staff in its investigation of a March 2014 explosion and fire and to review the prudence of the company's conduct associated with the incident. See "Manhattan Explosion and Fire" in Note H. In December 2015, the company responded that the NYSPSC should not institute the proceedings and disputed the alleged violations.

In February 2017, the NYSPSC approved a settlement agreement with CECONY related to the June 2014 plastic fusion proceeding and the November 2015 order to show cause. Pursuant to the settlement agreement, the company will not recover from customers $126 million of costs it incurred for gas emergency response activities in 2014, 2015 and 2016 in excess of amounts reflected in its gas rate plan for those years. At December 31, 2016, the company had not deferred any such incremental costs as a regulatory asset. In addition, the company will provide $27 million of future benefits to customers. At December 31, 2016, the Company had accrued a regulatory liability for these future benefits.

Regulatory Assets and Liabilities

Regulatory assets and liabilities at December 31, 2016 and 2015 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$2,874	$3,876	$2,730	$3,697
Future income tax	2,439	2,350	2,325	2,232
Environmental remediation costs	823	904	711	800
Revenue taxes	295	253	280	240
Deferred storm costs	56	185	3	110
Deferred derivative losses	48	50	42	46
Unamortized loss on reacquired debt	43	50	41	48
Recoverable energy costs	42	16	38	15
Pension and other postretirement benefits deferrals	38	45	7	16
O&R property tax reconciliation	37	46	—	—
Surcharge for New York State assessment	28	44	26	40
Preferred stock redemption	25	26	25	26
Net electric deferrals	24	44	24	44
O&R transition bond charges	15	21	—	—
Workers’ compensation	13	11	13	11
Other	224	175	208	157
Regulatory assets – noncurrent	7,024	8,096	6,473	7,482
Deferred derivative losses	91	113	86	103
Recoverable energy costs	9	19	4	18
Regulatory assets – current	100	132	90	121
Total Regulatory Assets	$7,124	$8,228	$6,563	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$755	$676	$641	$570
Pension and other postretirement benefit deferrals	193	76	162	46
Property tax reconciliation	178	303	178	303
Net unbilled revenue deferrals	145	109	145	109
Prudence proceeding	95	99	95	99
Carrying charges on repair allowance and bonus depreciation	68	49	67	48
New York State income tax rate change	61	75	60	72
Unrecognized other postretirement costs	60	28	60	28
Variable-rate tax-exempt debt - cost rate reconciliation	55	70	48	60
Base rate change deferrals	40	128	40	128
Earnings sharing - electric, gas and steam	39	80	28	80
Net utility plant reconciliations	16	32	15	31
Property tax refunds	1	44	1	44
World Trade Center settlement proceeds	—	21	—	21
Other	199	187	172	150
Regulatory liabilities – noncurrent	1,905	1,977	1,712	1,789
Revenue decoupling mechanism	71	45	61	45
Refundable energy costs	29	64	5	33
Deferred derivative gains	28	6	24	6
Regulatory liabilities—current	128	115	90	84
Total Regulatory Liabilities	$2,033	$2,092	$1,802	$1,873

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.

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

Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Superstorm Sandy and other major storms that were deferred by the Utilities.

Net electric deferrals represent the remaining unamortized balance of certain regulatory assets and liabilities of CECONY that were combined effective April 1, 2010 and are being amortized to income through March 31, 2018.

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

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 $145 million and $109 million at December 31, 2016 and 2015, respectively, for the difference between the unbilled revenues and energy cost liabilities.

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.

At December 31, 2016, the significant terms of the electricity purchase agreements with non-utility generators were as follows:

Facility	Equity Owner	Plant Output (MW)	Contracted Output (MW)	Contract Start Date	Contract Term (Years)
Brooklyn Navy Yard	Brooklyn Navy Yard Cogeneration Partners, LP	322	293	November 1996	40
Linden Cogeneration	Cogen Technologies Linden Venture, LP	974	630	May 1992	25
Indian Point	Entergy Nuclear Power Marketing, LLC	2,150	500	August 2001	16

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 contracts are estimated to be as follows:

(Millions of Dollars)	2017	2018	2019	2020	2021	All Years Thereafter
Con Edison	$178	$125	$120	$76	$54	$710
CECONY	178	125	119	75	54	710

For energy delivered under most of the electricity purchase agreements, CECONY is obligated to pay variable prices. The company’s payments under the agreements for capacity, energy and other fixed payments in 2016, 2015 and 2014 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
Linden Cogeneration	$304	$323	$381
Indian Point	203	226	247
Astoria Energy (a)	50	178	230
Astoria Generating Company	16	—	—
Brooklyn Navy Yard	119	113	133
Indeck Corinth (b)	—	25	80
Selkirk (c)	—	—	144
Independence (c)	—	—	97
Total	$692	$865	$1,312

(a) Contract term ended in 2016.

(b) Contract term ended in 2015.

(c) Contract term ended in 2014

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Leases

12 Months Ended

Dec. 31, 2016

Leases [Abstract]

Leases

Leases

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

Capital leases: For ratemaking purposes capital leases are treated as operating leases; therefore, in accordance with the accounting rules for regulated operations, the amortization of the leased asset is based on the rental payments recovered from customers. The following assets under capital leases are included in the Companies’ consolidated balance sheets at December 31, 2016 and 2015:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
UTILITY PLANT
Common	$3	$3	$2	$2

The accumulated amortization of the capital leases for Con Edison and CECONY was $3 million and $1 million, respectively at December 31, 2016, and $3 million and $2 million, respectively at December 31, 2015.

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

(Millions of Dollars)	Con Edison	CECONY
2017	$1	$1
2018	1	1
2019	—	—
2020	—	—
2021	—	—
All years thereafter	—	—
Total	2	2
Less: amount representing interest	—	—
Present value of net minimum lease payment	$2	$2

Operating leases: The future minimum lease commitments under the Companies’ operating lease agreements that are not cancellable by the Companies are as follows:

(Millions of Dollars)	Con Edison	CECONY
2017	$61	$53
2018	62	54
2019	61	54
2020	61	54
2021	58	53
All years thereafter	788	696
Total	$1,091	$964

Substantially all of the amounts shown in the above table are estimated amounts payable under CECONY’s revocable consent agreement with New York City for the use of streets and public places for installation and operation of transformers and associated vaults and equipment. Under the agreement, payments by CECONY increase 2.18 percent annually and are subject to decrease if CECONY’s transformer installations decrease by ½ of 1 percent or more from the prior year.

For information about changes to the accounting rules for leases, see Note T.

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Goodwill and Other Intangible Assets

12 Months Ended

Dec. 31, 2016

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangible Assets

Goodwill and Other Intangible Assets

In 2016 and 2015, Con Edison completed impairment tests for its goodwill of $406 million related to the O&R merger, and determined that it was not impaired. For the impairment test, $245 million and $161 million of the goodwill were allocated to CECONY and O&R, respectively. In 2016 and 2015, Con Edison completed impairment tests for the goodwill of $23 million related to two energy services companies owned by Con Edison Solutions and a gas storage company owned by Con Edison Development. In 2015, Con Edison determined that the goodwill was not impaired. In 2016, Con Edison determined that goodwill related to the two energy services companies was impaired and upon calculating the implied fair value of goodwill using fair values based primarily on discounted cash flows, recorded a corresponding impairment charge of $15 million ($12 million, net of tax). In 2016, Con Edison determined that goodwill related to the gas storage company was not impaired. Additionally, in 2016, Con Edison Solutions acquired a residential solar company and recorded $14 million of goodwill as part of the preliminary purchase price allocation. Estimates of future cash flows, projected growth rates, and discount rates inherent in the cash flow estimates for the gas storage company and residential solar company may vary significantly from actual results, which could result in a future impairment of goodwill.

For information about changes to the accounting rules for goodwill, see Note T.

Con Edison's other intangible assets consist primarily of power purchase agreements, which were identified as part of purchase price allocations associated with acquisitions made by Con Edison Development in 2016 (see Note U). At December 31, 2016, intangible assets arising from power purchase agreements were $119 million, net of accumulated amortization of $1 million, and are being amortized over the life of each agreement. Excluding power purchase agreements, Con Edison’s other intangible assets were $5 million and $2 million, net of accumulated amortization of $5 million and $4 million, at December 31, 2016 and 2015, respectively. CECONY’s other intangible assets were immaterial at December 31, 2016 and 2015. Con Edison recorded amortization expense related to its intangible assets of $2 million in 2016, and immaterial amounts in 2015 and 2014. Con Edison expects amortization expense to be $8 million per year over the next five years.

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Income Tax

12 Months Ended

Dec. 31, 2016

Income Tax Disclosure [Abstract]

Income Tax

Income Tax

The components of income tax are as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
State
Current	$(42)	$38	$59	$(1)	$48	$66
Deferred	188	93	61	114	82	65
Federal
Current	(43)	(86)	(9)	59	77	158
Deferred	604	569	463	435	372	271
Amortization of investment tax credits	(9)	(9)	(6)	(4)	(5)	(5)
Total income tax expense	$698	$605	$568	$603	$574	$555

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

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Deferred tax liabilities:
Property basis differences	$9,446	$8,614	$8,620	$7,922
Regulatory assets:
Unrecognized pension and other postretirement costs	1,162	1,562	1,104	1,490
Future income tax	986	947	940	899
Environmental remediation costs	333	365	287	322
Deferred storm costs	23	75	1	45
Other regulatory assets	371	367	321	308
Equity investments	363	295	—	—
Total deferred tax liabilities	$12,684	$12,225	$11,273	$10,986
Deferred tax assets:
Accrued pension and other postretirement costs	$581	$982	$467	$857
Regulatory liabilities	822	836	728	752
Superfund and other environmental costs	304	308	265	268
Asset retirement obligations	99	97	92	94
Loss carryforwards	59	29	—	—
Tax credits carryforward	498	258	—	1
Valuation allowance	(16)	(15)	—	—
Other	303	362	312	292
Total deferred tax assets	2,650	2,857	1,864	2,264
Net deferred tax liabilities	$10,034	$9,368	$9,409	$8,722
Unamortized investment tax credits	171	169	41	33
Net deferred tax liabilities and unamortized investment tax credits	$10,205	$9,537	$9,450	$8,755

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)	2016		2015		2014		2016		2015		2014
STATUTORY TAX RATE
Federal	35	%	35	%	35	%	35	%	35	%	35	%
Changes in computed taxes resulting from:
State income tax	4		5		5		4		5		5
Cost of removal	(1	)	(5	)	(5	)	(1	)	(5	)	(5	)
Renewable energy credits	(1	)	(1	)	—		—		—		—
Research and development credits	(1	)	—		—		(1	)	—		—
Other	—		—		(1	)	(1	)	—		(1	)
Effective tax rate	36	%	34	%	34	%	36	%	35	%	34	%

In 2016, Con Edison had a federal net operating loss of approximately $204 million, primarily due to bonus depreciation. Con Edison expects to carryback approximately $178 million of its 2016 net operating loss to 2007 and 2014, which will result in recovery of $32 million of income tax and reestablishment of $31 million of general business tax credits. The remaining 2016 federal net operating loss of $26 million will be carried forward to future years and will not expire until 2036. General business tax credits that were generated in 2016 ($207 million) and became available as a result of the net operating loss carryback ($31 million) will be carried forward to future years. Con Edison has $498 million in general business tax credit (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 has been provided, as it is more likely than not that the deferred tax asset will be realized.

Con Edison recorded a full valuation allowance of $3 million in 2015 against its charitable contribution carryforward from 2011. Due to the expiration of this charitable contribution carryforward in 2016, Con Edison wrote off the deferred tax asset and corresponding valuation allowance. Charitable contributions carryforward of $5 million and $6 million for 2015 and 2016, respectively, that will expire in 2020 and 2021, respectively, were recorded as a deferred tax asset and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized. In addition, a $12 million valuation allowance for New York City net operating loss carryforward and a $4 million valuation allowance for state net operating losses carryforward has been provided; as it is not more likely than not that the deferred tax asset will be realized.

In 2014, tax legislation was enacted in the State of New York that reduced the corporate franchise tax rate from 7.1 percent to 6.5 percent, beginning January 1, 2016. The application of this legislation decreased Con Edison’s accumulated deferred tax liabilities by $74 million ($69 million for CECONY), decreased Con Edison’s regulatory asset for future income tax by $11 million ($10 million for CECONY) and increased Con Edison’s regulatory liability by $62 million ($59 million for CECONY). The impact of this tax legislation on Con Edison’s effective tax rate was not material, and there was no impact on CECONY’s effective tax rate for the year ended December 31, 2014.

Under the Taxpayer Relief Act of 2012, 50 percent bonus depreciation expired on December 31, 2013. The Tax Increase Prevention Act of 2014 extended bonus depreciation for another year through December 31, 2014. As a result of the extension of bonus depreciation to 2014, Con Edison filed a refund request with the IRS in January 2015 to recover$224 million($128 millionfor CECONY) in estimated federal tax payments and received the refund in March 2015.

The Protecting Americans from Tax Hikes Act of 2015 extended bonus depreciation for property acquired and placed in service during 2015 through 2019. The bonus depreciation percentage is50 percentfor property placed in service during 2015, 2016 and 2017 and phases down to40 percentin 2018, and30 percentin 2019. As a result of the extension of bonus depreciation to 2015, Con Edison filed a refund request with the IRS in January 2016 to recover$160 millionin estimated federal tax payments. In February 2016, Con Edison received a refund of estimated taxes paid in the amount of $160 million ($143 million for CECONY).

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)	2016	2015	2014	2016	2015		2014
Balance at January 1,	$34	$34	$9	$2		$2		$—
Additions based on tax positions related to the current year	2	—	—	2	—		—
Additions based on tax positions of prior years	19	1	27	19	—		2
Reductions for tax positions of prior years	(13)	—	(2)	(2)	—		—
Reductions from expiration of statute of limitations	—	(1)	—	—	—		—
Settlements	—	—	—	—	—		—
Balance at December 31,	$42	$34	$34	$21	$2		$2

In 2016, Con Edison reached a settlement with New York State on two claims it had filed in previous years and reversed $11 million in uncertain tax positions. Of this amount, $8 million ($5 million, net of federal taxes) reduced Con Edison’s effective tax rate. The amount related to CECONY was $2 million ($1 million, net of federal taxes), all of which reduced CECONY’s effective tax rate. Current year additions of $21 million are for tax credits and prior years' claims filed in 2016.

As of December 31, 2016, Con Edison reasonably expects to resolve within the next twelve months approximately $35 million ($24 million, net of federal taxes) of various federal and state uncertainties due to the expected completion of ongoing tax examinations, including $21 million ($14 million, net of federal taxes), which, if recognized, would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $17 million ($12 million, net of federal taxes), including $2 million, which, if recognized, would reduce CECONY’s effective tax rate.

The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In 2016, 2015 and 2014, the Companies recognized an immaterial amount of interest and no penalties for uncertain tax positions in their consolidated income statements. At December 31, 2016 and 2015, the Companies recognized an immaterial amount of interest and no penalties in their consolidated balance sheets.

At December 31, 2016, the total amount of unrecognized tax benefits that, if recognized, would reduce the Companies’ effective tax rate is $24 million ($17 million, net of federal taxes) with $3 million attributable to CECONY.

The federal tax returns for 2012 through 2015 remain open for examination. State income tax returns remain open for examination in New York for tax years 2006 through 2015 and in New Jersey for tax years 2008 through 2015.

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Stock-Based Compensation

12 Months Ended

Dec. 31, 2016

Disclosure of Compensation Related Costs, Share-based Payments [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 (authorized, but unissued) shares, treasury shares or shares purchased in the open market. The shares used during the year ended December 31, 2016 were new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2017.

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, 2016, 2015 and 2014:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Performance-based restricted stock	$42	$27	$22	$36	$23	$19
Time-based restricted stock	2	1	2	2	1	2
Non-employee director deferred stock compensation	2	2	2	2	2	2
Stock purchase plan	4	4	3	4	3	3
Total	$50	$34	$29	$44	$29	$26
Income tax benefit	$20	$14	$12	$18	$12	$10

Stock Options

The Companies last granted stock options in 2006. The stock options generally vested over a three-year period and had a term of 10 years. Options were granted at an exercise price equal to the fair market value of a common share when the option was granted. The Companies generally recognized compensation expense (based on the fair value of stock option awards) over the vesting period. No outstanding options remain as of December 31, 2016.

A summary of changes in the status of stock options as of December 31, 2016 is as follows:

	Con Edison		CECONY
	Shares	Weighted Average Exercise Price	Shares	Weighted Average Exercise Price
Outstanding at December 31, 2015	79,125	$43.50	65,775	$43.50
Exercised	79,125	43.50	65,775	43.50
Forfeited	—	—	—	—
Outstanding at December 31, 2016	—	$—	—	$—

The following table summarizes information about stock options for the years ended December 31, 2016 and 2015:

	Con Edison			CECONY
(Millions of Dollars)	2016		2015	2016		2015
Aggregate intrinsic value (a)
Options outstanding		$—	$2		$—	$1
Options exercised	2		3	2		3
Cash received by Con Edison for payment of exercise price	3		6	3		5

(a) Aggregate intrinsic value represents the changes in the fair value of all outstanding options from their grant dates to December 31 of the years presented above.

The income tax benefit Con Edison realized from stock options exercised in the years ended December 31, 2016, 2015 and 2014 was $1 million.

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 represents 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:

	2016	2015	2014
Risk-free interest rate (a)	0.85% - 1.20%	0.64% - 3.28%	0.23% - 3.07%
Expected term (b)	3 years	3 years	3 years
Expected share price volatility (c)	17.72% - 18.22%	15.82%	13.14%

(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, 2016 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, 2015	1,078,339	$45.26	$58.08	853,257	$45.37	$58.12
Granted	386,400	83.16	72.10	295,300	82.73	72.34
Vested	(351,230)	55.16	57.96	(285,162)	55.21	58.07
Forfeited	(26,372)	48.48	61.03	(15,053)	53.61	63.05
Non-vested at December 31, 2016	1,087,137	$55.45	$63.03	848,342	$54.92	$63.00

(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, 2016 is $34 million, including $27 million for CECONY, and is expected to be recognized over a weighted average period of one year for both Con Edison and CECONY.

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, 2016 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, 2015	64,980	$58.56	61,630	$58.55
Granted	23,000	76.62	21,800	76.62
Vested	(20,900)	61.03	(19,800)	61.03
Forfeited	(1,100)	60.13	(1,050)	60.43
Non-vested at December 31, 2016	65,980	$64.04	62,580	$64.03

The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2016 for Con Edison and CECONY was $2 million and is expected to be recognized over a weighted average period of one year.

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, 2016, approximately 27,600 units were issued at a weighted average grant date price of $74.37.

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. 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 2016, 2015 and 2014, 720,268, 761,784 and 708,276 shares were purchased under the Stock Purchase Plan at a weighted average price of $72.67, $62.75 and $56.23 per share, respectively.

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Financial Information by Business Segment

12 Months Ended

Dec. 31, 2016

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. Con Edison Transmission, which had begun investing in electric transmission and gas pipeline and storage assets (see Note U), was added in June 2016 as a separate reportable segment based on management’s reporting and decision-making, including performance evaluation and resource allocation. For comparison purposes, the previously reported financial information by business segments was reclassified to reflect the current business segment presentation.

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, 2016 (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	$8,106	$17		$865	$1,847	$2		$459	$495	$30,708	$1,819
Gas	1,508	6		159	357	(1)		105	92	7,553	811
Steam	551	88		82	58	(1)		39	30	2,595	126
Consolidation adjustments	—	(111)		—	—	—		—	—	—	—
Total CECONY	$10,165		$—	$1,106	$2,262		$—	$603	$617	$40,856	$2,756
O&R
Electric	$637		$—	$49	$95	$1		$24	$30	$1,949	$114
Gas	184	—		18	35	—		12	10	809	52
Other	—	—		—	—	—		—	—	—	—
Total O&R	$821		$—	$67	$130	$1		$36	$40	$2,758	$166
Clean Energy Businesses	$1,091	$7		$42	$183	$21		$34	$53	$2,551	$1,235
Con Edison Transmission	—	—		—	(3)	43		6	—	1,150	1,078
Other (b)	(2)	(7)		1	3	(1)		17	4	940	—
Total Con Edison	$12,075		$—	$1,216	$2,575	$64		$696	$714	$48,255	$5,235

As of and for the Year Ended December 31, 2015 (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 (c)	Capital expenditures
CECONY
Electric	$8,172	$18		$820	$1,798	$(2)	$447	$447	$30,603	$1,658
Gas	1,527	6		142	356	(2)	96	100	6,974	671
Steam	629	86		78	93	(1)	41	41	2,653	106
Consolidation adjustments	—	(110)		—	—	—	—	—	—	—
Total CECONY	$10,328		$—	$1,040	$2,247	$(5)	$584	$588	$40,230	$2,435
O&R
Electric	$663		$—	$50	$103	$(2)	$23	$31	$2,140	$114
Gas	182	—		18	18	(2)	12	2	579	46
Other	—	—		—	—	—	—	—	—	—
Total O&R	$845		$—	$68	$121	$(4)	$35	$33	$2,719	$160
Clean Energy Businesses	$1,383	$(2)		$22	$58	$35	$11	$22	$1,680	$823
Con Edison Transmission	—	—		—	—	—	—	—	3	—
Other (b)	(2)	2		—	1	(2)	23	1	1,010	—
Total Con Edison	$12,554		$—	$1,130	$2,427	$24	$653	$644	$45,642	$3,418

As of and for the Year Ended December 31, 2014 (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 (c)	Capital expenditures
CECONY
Electric	$8,437	$16		$781	$1,712	$8	$412	$425	$30,295	$1,500
Gas	1,721	6		132	314	2	89	88	6,478	549
Steam	628	84		78	113	1	36	49	2,670	83
Consolidation adjustments	—	(106)		—	—	—	—	—	—	—
Total CECONY	$10,786		$—	$991	$2,139	$11	$537	$562	$39,443	$2,132
O&R
Electric	$680		$—	$46	$103	$3	$24	$29	$2,023	$105
Gas	212	—		15	25	—	10	6	786	37
Other	—	—		—	—	—	1	—	1	—
Total O&R	$892		$—	$61	$128	$3	$35	$35	$2,810	$142
Clean Energy Businesses	$1,244	$(10)		$19	$(60)	$28	$(8)	$(8)	$1,013	$447
Con Edison Transmission	—	—		—	—	—	—	—	1	—
Other (b)	(3)	10		—	2	—	27	—	804	—
Total Con Edison	$12,919		$—	$1,071	$2,209	$42	$591	$589	$44,071	$2,721

(a) For Con Edison, the income tax expense on non-operating income was $16 million, $40 million and $21 million in 2016, 2015 and 2014, respectively. For CECONY, the income tax expense on non-operating income was $14 million, $14 million and $7 million in 2016, 2015 and 2014, respectively.

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

(c) Reflects $237 million in 2014, related to the adoption of ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs” and ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes.” See Notes C and L.

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Derivative Instruments and Hedging Activities

12 Months Ended

Dec. 31, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities

Commodity Derivatives

Con Edison’s subsidiaries hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. Derivatives are recognized on the consolidated balance sheet at fair value (see Note P), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules.

The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at December 31, 2016 and 2015 were:

(Millions of Dollars)	2016				2015
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	$81	$(64)	$17	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	49	(43)	6		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$130	$(107)	$23		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(138)	$61	$(77)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(91)	52	(39)	(d)	(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(229)	$113	$(116)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(99)	$6	$(93)	(b)(d)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(45)	$7	(b)	$40	$(32)	$8	(b)
Noncurrent	41	(35)	6		48	(47)	1
Total fair value of derivative assets	$93	$(80)	$13		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(111)	$45	$(66)		$(121)	$71	$(50)
Noncurrent	(77)	44	(33)		(92)	56	(36)
Total fair value of derivative liabilities	$(188)	$89	$(99)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(95)	$9	$(86)	(b)	$(125)	$48	$(77)	(b)

(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, 2016 and 2015, margin deposits for Con Edison ($7 million and $26 million, respectively) and CECONY ($7 million and $26 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) Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet.

(d) Does not include ($1) million for interest rate swap (see below).

The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. 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 purchased power, gas purchased for resale and non-utility revenue in the reporting period in which they occur. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the years ended December 31, 2016 and 2015:

		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016			2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$23		$1		$18			$2
Noncurrent	Deferred derivative gains	1		1		2			—
Total deferred gains/(losses)		$24		$2		$20			$2
Current	Deferred derivative losses	$22		$(16)		$18			$(11)
Current	Recoverable energy costs	(212)		(136)		(194)			(127)
Noncurrent	Deferred derivative losses	2		(25)		4			(23)
Total deferred gains/(losses)		$(188)		$(177)		$(172)			$(161)
Net deferred gains/(losses)		$(164)		$(175)		$(152)			$(159)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(101)	(a)	$(109)	(b)		$—			$—
	Gas purchased for resale	(112)		(106)		—			—
	Non-utility revenue	9	(a)	30	(b)	—			—
	Other operations and maintenance expense	1	(c)	(1)	(d)	1		(c)	(1)		(d)
Total pre-tax gain/(loss) recognized in income		$(203)		$(186)		$1			$(1)

(a) For the year ended December 31, 2016, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($5 million loss) and purchased power expense ($11 million gain).

(b) For the year ended December 31, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($1 million gain) and purchased power expense ($1 million loss).

(c) For the year ended December 31, 2016, Con Edison and CECONY recorded an unrealized gain in other operations and maintenance expense ($1 million).

(d) For the year ended December 31, 2015, Con Edison and CECONY recorded an unrealized loss in other operations and maintenance expense ($1 million).

The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at December 31, 2016:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	21,235,830	13,616	77,248,786	3,696,000
CECONY	19,258,400	7,500	71,060,000	3,696,000

(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, 2016, Con Edison and CECONY had $62 million and $20 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $25 million with commodity exchange brokers, $17 million with investment-grade counterparties, $11 million with non-investment grade/non-rated counterparties and $9 million with independent system operators. CECONY’s net credit exposure consisted of $14 million with commodity exchange brokers and $6 million with investment-grade counterparties.

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

The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at December 31, 2016:

(Millions of Dollars)	Con Edison (a)	CECONY (a)
Aggregate fair value – net liabilities	$113	$103
Collateral posted	43	42
Additional collateral (b) (downgrade one level from current ratings)	11	10
Additional collateral (b)(c) (downgrade to below investment grade from current ratings)	75	65

(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 $43 million at December 31, 2016. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) Derivative instruments that are net assets have been excluded from the table. At December 31, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $15 million.

Interest Rate Swap

In December 2016, the Clean Energy Businesses acquired Coram Wind (see Note U) which holds an interest rate swap that terminates in June 2024, pursuant to which it pays a fixed-rate of 2.0855 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap at the time of acquisition was a liability of $1 million which was added to Con Edison’s consolidated balance sheet. Subsequent changes to the fair value after the date of acquisition are recorded in the company’s consolidated income statement as other interest expense and were immaterial for the year ended December 31, 2016.

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Fair Value Measurements

12 Months Ended

Dec. 31, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurements

Fair Value Measurements

The accounting rules for fair value measurements and disclosures define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.

The accounting rules for fair value measurements and disclosures established a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows:

• Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange.

• Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models.

• Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value.

Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2016 and 2015 are summarized below.

	2016						2015
(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)	$14	$33	$7		$(24)	$30	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	—	—		—	—	—	63	1		(63)	1
Other (a)(b)(d)	222	111	—		—	333	185	112	—		—	297
Total assets	$236	$144	$7		$(24)	$363	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$4	$144	$6		$(38)	$116	$16	$153	$1		$(65)	$105
Interest Rate Swap (a)(b)(c)(g)	—	1	—		—	1	—	—	—		—	—
Commodity held for sale (f)	—	—	—		—	—	1	133	7		(63)	78
Total liabilities	$4	$145	$6		$(38)	$117	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$10	$19	$1		$(10)	$20	$1	$9	$8		$17	$35
Other (a)(b)(d)	200	106	—		—	306	171	105	—		—	276
Total assets	$210	$125	$1		$(10)	$326	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$1	$124		$—	$(26)	$99	$14	$129		$—	$(57)	$86

(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. There were no transfers between levels 1, 2 and 3 for the years ended December 31, 2016 and 2015.

(b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, interest rate swap, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.

(c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2016 and 2015, 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) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet (see Note U).

(g) See Note O.

The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity derivatives. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives. Fair value and changes in fair value of commodity derivatives are reported on a monthly basis to the Companies’ risk committees, comprised of officers and employees of the Companies that oversee energy hedging at the Utilities and the Clean Energy Businesses. The risk management group reports to the Companies’ Vice President and Treasurer.

	Fair Value of Level 3 at December 31, 2016
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison — Commodity
Electricity	$(1)	Discounted Cash Flow	Forward energy prices (a)	$37.75-$55.00 per MWh
		Discounted Cash Flow	Forward capacity prices (a)	$2.42-$10.25 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	2	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
			Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(75.2)%-58.9%
			Inter-zonal forward price curves adjusted for historical zonal losses (b)	$1.11-$2.90 per MWh
Total Con Edison — Commodity	$1
CECONY — Commodity
Transmission Congestion Contracts	$1	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
			Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(75.2)%-58.9%

(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, 2016 and 2015 and classified as Level 3 in the fair value hierarchy:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of January 1,	$6	$20	$8	$13
Included in earnings	(7)	(20)	(1)	(6)
Included in regulatory assets and liabilities	(6)	1	(6)	—
Purchases	4	11	2	5
Sales (a)	4	—	—	—
Settlements	—	(6)	(2)	(4)
Ending balance as of December 31,	$1	$6	$1	$8

(a)Amounts represent derivative instruments novated as part of the assets of Con Edison Solutions’ retail electric supply business which were sold to a subsidiary of Exelon Corporation (see Note U).

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 (immaterial for both years) and purchased power costs ($6 million loss and $14 million loss) on the consolidated income statement for the years ended December 31, 2016 and 2015, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at December 31, 2016 and 2015 is included in non-utility revenues (immaterial for both years) and purchased power costs ($1 million loss and $8 million loss) on the consolidated income statement for the years ended December 31, 2016 and 2015, respectively.

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Variable Interest Entities

12 Months Ended

Dec. 31, 2016

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.

Con Edison enters into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, Con Edison retains or may retain a variable interest in these entities.

CECONY

CECONY had a variable interest in a non-consolidated VIE, Astoria Energy, LLC (Astoria Energy), with which CECONY entered into a long-term electricity purchase agreement that expired in April 2016. CECONY has ongoing long-term electricity purchase agreements with the following two potential VIEs: Cogen Technologies Linden Venture, LP and Brooklyn Navy Yard Cogeneration Partners, LP. In 2016, requests were made of these counterparties for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. See Note I for information on these electricity purchase agreements, the payments pursuant to which constitute CECONY's maximum exposure to loss with respect to the potential VIEs.

Con Edison Development

Con Edison has a variable interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), which is a consolidated entity in which Con Edison Development has an 80 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project in Texas. Electricity generated by the project is sold to the City of San Antonio pursuant to a long-term power purchase agreement. At December 31, 2016 and 2015, Con Edison’s consolidated balance sheet includes $54 million and $58 million in net assets (as detailed in the table below) and the noncontrolling interest of the third party of $7 million and $9 million related to Texas Solar 4, respectively. Earnings for the year ended December 31, 2016 and 2015 were immaterial.

(Millions of Dollars)	2016	2015
Restricted cash	$8	$9
Receivable from parent company	35	32
Non-utility property, less accumulated depreciation of $9 and $5, respectively	104	107
Other assets	8	11
Total assets (a)	$155	$159
Long-term debt due within one year	$3	$2
Other liabilities	38	37
Long-term debt	60	62
Total liabilities (b)	$101	$101

(a) The assets of Texas Solar 4 represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE.

(b) The liabilities of Texas Solar 4 represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary.

The following table summarizes the VIEs in which Con Edison Development has entered into as of December 31, 2016:

Project Name (a)	Generating Capacity (b) (MW AC)	Power Purchase Agreement Term in Years	Year of Initial Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (c)
Copper Mountain Solar 3	128	20	2014	Nevada	$179
Mesquite Solar 1	83	20	2013	Arizona	108
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	69
Broken Bow II	38	25	2014	Nebraska	48
Texas Solar 4	32	25	2014	Texas	47

(a) With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. With the exception of Texas Solar 4, Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development.

(b) Represents Con Edison Development’s ownership interest in the project.

(c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet. For consolidated investments, such as Texas Solar 4, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest ($7 million for Texas Solar 4). Con Edison did not provide any financial or other support during the year that was not previously contractually required.

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Asset Retirement Obligations

12 Months Ended

Dec. 31, 2016

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.

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, 2016, the liabilities for asset retirement obligations of Con Edison and CECONY were $246 million and $227 million, respectively. At December 31, 2015, the liabilities for asset retirement obligations of Con Edison and CECONY were $242 million and $234 million, respectively. The change in liabilities at December 31, 2016 was due to changes in estimated cash flows of $29 million and $19 million for Con Edison and CECONY, respectively, and accretion expense of $10 million and $9 million for Con Edison and CECONY, respectively. The changes were offset by liabilities settled of $35 million for both Con Edison and CECONY. Con Edison and CECONY also recorded reductions of $37 million and $23 million during the years ended December 31, 2016 and 2015, 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, 2016

Related Party Transactions [Abstract]

Related Party Transactions

Related Party Transactions

The Utilities and the Clean Energy Businesses provide administrative and other services to each other pursuant to cost allocation procedures approved by the NYSPSC. The costs of administrative and other services provided by CECONY to, and received by it from, Con Edison and its other subsidiaries for the years ended December 31, 2016, 2015 and 2014 were as follows:

	CECONY
(Millions of Dollars)	2016	2015	2014
Cost of services provided	$108	$99	$90
Cost of services received	64	60	57

In addition, CECONY and O&R have joint gas supply arrangements, in connection with which CECONY sold to O&R $47 million, $54 million and $80 million of natural gas for the years ended December 31, 2016, 2015 and 2014, 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 year ended December 31, 2016, the amounts billed by the Utilities to NY Transco were immaterial. In May 2016, CECONY transferred certain electric transmission projects to NY Transco (see Note U).

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) (see Note U). In addition, CECONY is the replacement shipper on one of Crestwood’s firm transportation agreements with Tennessee Gas Pipeline Company LLC. From the inception of the joint venture in June 2016 through December 31, 2016, the amount of storage and wheeling services received by CECONY from Stagecoach was $18 million. In addition, the Clean Energy Businesses entered into two electricity sales agreements with Stagecoach under which the amounts received in 2016 were immaterial.

CECONY has a financial electric capacity contract with Con Edison Energy for the period May 2016 through April 2017. For the year ended December 31, 2016, Con Edison Energy's realized gains under this contract were immaterial.

FERC has authorized CECONY through 2017 to lend funds to O&R from time to time, for periods of not more than 12 months, in amounts not to exceed $250 million outstanding at any time, at prevailing market rates. There were no outstanding loans to O&R at December 31, 2016 and 2015.

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New Financial Accounting Standards

12 Months Ended

Dec. 31, 2016

Accounting Changes and Error Corrections [Abstract]

New Financial Accounting Standards

New Financial Accounting Standards

In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board jointly issued a revenue recognition standard that will supersede the revenue recognition requirements within Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. Amendments were issued subsequently to clarify key areas including principal/agent considerations, performance obligations, licensing, sales taxes, noncash consideration, and contracts. The new standard is effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for reporting periods beginning after December 15, 2016, however, the Companies plan to adopt the new standard for reporting periods beginning after December 15, 2017.

Under the new standard, companies may use either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a modified retrospective approach with the cumulative effect of initially adopting ASU 2014-09 recognized at the date of adoption (which includes additional footnote disclosures). The Companies anticipate using the modified retrospective approach.

The Companies are currently in the process of evaluating the impact of the new standard on their various revenue streams. The majority of the Companies’ sales are derived from tariffs to provide electric, gas, and steam service to customers. For such tariffs, the Companies expect that the revenue from contracts with the customer under ASU 2014-09 will be equivalent to the electricity, gas, or steam supplied in that period which is consistent with current practice. Consequently, the Companies do not anticipate that the new standard will significantly impact the amount and/or timing of such revenues. The Companies continue to review the potential impacts of other revenue at the Utilities and the Clean Energy Businesses on the Companies' financial position, results of operations and liquidity as well as the additional disclosures required under the new standard.

In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. Based on the existing portfolio of leases at implementation, for leases currently classified as operating leases, the Companies expect to recognize on the statements of financial position right-of-use assets and lease liabilities. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ results of operations and liquidity.

In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” The amendments require that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning after December 15, 2016. The company elected to early adopt this standard as permitted, and it did not have a material impact on the Companies’ financial position, results of operations and liquidity.

In May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of ASU 2014-09 and 2014-16. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In August 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force).” The amendment specifies the classification and presentation of certain cash flow items to reduce diversity in practice. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In October 2016, the FASB issued amendments to the guidance for Income Taxes through ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory).” The amendment clarifies the tax treatment of intra-entity transfers of assets other than inventory. The updated guidance requires entities to recognize the income tax consequences of an intra-entity transfer of assets other than inventory when the transfer occurs. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In October 2016, the FASB issued amendments to the guidance for Consolidation through ASU 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control.” The amendments in this update change how a single decision maker of a VIE will consider its indirect interests in a VIE held by related parties under common control when performing the primary beneficiary analysis. If a single decision maker and its related parties are under common control, the single decision maker must evaluate indirect interests on a proportionate basis when evaluating whether it is a primary beneficiary of the VIE. The guidance does not change the characteristics of a primary beneficiary under GAAP but has amended the considerations in the evaluation of determining the primary beneficiary of a VIE under common control. For public entities, the amendments are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In November 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-18, “Update 2016-18-Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force).” The amendments in this update clarify the presentation of changes in restricted cash and restricted cash equivalents in the statement of cash flows. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In January 2017, the FASB issued amendments to the guidance for Business Combinations through ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business.” The amendments in this update clarify the definition of a business and provide guidance on evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In January 2017, the FASB issued amendments to the guidance for the subsequent measurement of goodwill through ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The amendments in this update simplify goodwill impairment testing by eliminating Step 2 of the goodwill impairment test wherein an entity has to compute the implied fair value of goodwill by performing procedures to determine the fair value of its assets and liabilities. Under the new guidance, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value up to the total amount of goodwill allocated to that reporting unit. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

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Acquisitions, Investments and Dispositions

12 Months Ended

Dec. 31, 2016

Business Combinations [Abstract]

Acquisitions, Investments and Dispositions

Acquisitions, Investments and Dispositions

Acquisitions and Investments

Texas Solar 7

In January 2016, Con Edison Development acquired a 100 percent equity interest in a company that is the owner of a 106 MW (AC) solar electric production project in Texas (Texas Solar 7) for $227 million, as to which $218 million was recorded as non-utility construction work in progress and the remaining $9 million was recorded as other receivables. At December 31, 2016 net assets of the project were approximately $127 million, inclusive of $41 million in an intangible asset recorded as an adjustment to the purchase price allocation in December 2016. The intangible asset pertains to the value of the project's power purchase agreement, relative to current market rates, and is being amortized over the life of the agreement. The project has been financed, in part, by debt secured by the project. Electricity generated by this project is to be purchased by the City of San Antonio pursuant to a long-term power purchase agreement. The project commenced commercial operation in the third quarter of 2016. Con Edison's equity interest in Texas Solar 7 is consolidated in the financial statements.

Mountain Valley Pipeline

In January 2016, CET Gas acquired a 12.5 percent equity interest in Mountain Valley Pipeline, LLC (MVP), a company developing a proposed gas transmission project in West Virginia and Virginia. The company's initial contribution to MVP was $18 million. At December 31, 2016, CET Gas' investment in MVP was $48 million. The estimated total project cost is $3,000 million to $3,500 million. Subject to FERC approval, MVP is targeting to be fully in-service during 2018. Con Edison is accounting for its equity interest in MVP as an equity method investment.

NY Transco

In January 2016, CECONY entered into an agreement to transfer certain electric transmission projects to NY Transco, a company in which CET Electric has a 45.7 percent equity interest. In April 2016, the NYSPSC authorized CECONY, subject to certain conditions, to transfer the projects to NY Transco. In May 2016, CECONY transferred the projects to NY Transco for a purchase price of $122 million and an $8 million payment for easement rights on certain associated property. At December 31, 2016, CET Electric's investment in NY Transco was $51 million. Con Edison is accounting for its equity interest in NY Transco as an equity method investment.

Stagecoach Gas Services

In April 2016, a CET Gas subsidiary agreed with a subsidiary of Crestwood to form a joint venture to own, operate and further develop existing gas pipeline and storage businesses located in northern Pennsylvania and southern New York. The transaction was substantially completed in June 2016, and the remainder was completed in November 2016. Crestwood contributed businesses to a new entity, Stagecoach, and the CET Gas subsidiary purchased a 50 percent equity interest in Stagecoach for $974 million. At December 31, 2016, CET Gas' investment in Stagecoach was $992 million. Con Edison is accounting for its equity interest in Stagecoach as an equity method investment.

Pilesgrove

In June 2016, Con Edison Development recorded an $8 million ($5 million, net of taxes) impairment charge on its 50 percent equity interest in Pilesgrove Solar, LLC (Pilesgrove), which owns an 18 MW (AC) solar electric production project in New Jersey. In August 2016, Con Edison Development acquired the remaining 50 percent equity interest in Pilesgrove for a purchase price of approximately $16 million and recorded a bargain purchase gain of $8 million ($5 million, net of taxes); $45 million was recorded as non-utility property and the remaining $3 million was recorded as current assets. The impairment charge and bargain purchase gain are included in Investment and other income on Con Edison’s consolidated income statement. Con Edison's equity interest in Pilesgrove is consolidated in the financial statements. At December 31, 2016, net assets of the project were approximately $45 million.

Panoche Valley

In October 2016, Con Edison Development, which owned a 50 percent equity interest, acquired the remaining 50 percent equity interest in Panoche Holdings, LLC (Panoche), which is developing a 240 MW (AC) solar electric production project in California, for cash consideration of $28 million and the release of Panoche from its obligation under a $242 million note payable to Con Edison Development. At the time of acquisition, $290 million was recorded as non-utility construction work in process, $22 million was recorded as other assets and $14 million was recorded as current liabilities. The amounts recorded are subject to adjustments to the preliminary purchase price allocation. Con Edison's equity interest in Panoche is consolidated in the financial statements. At December 31, 2016, net assets of the project were approximately $388 million.

Coram Wind

In December 2016, Con Edison Development acquired a 100 percent equity interest in Coram California Development, LP (Coram), which owns a 102 MW (AC) wind electric production project in California for $97 million, as to which $191 million was recorded as non-utility property, $78 million was recorded as an intangible asset, $8 million of restricted cash was recorded as other current assets, and $180 million was recorded as long term debt. The intangible asset pertains to the value of the project's power purchase agreement, relative to current market rates, and is being amortized over the life of the agreement. The amounts recorded are subject to adjustments to the preliminary purchase price allocation. The project commenced commercial operation in March 2012. Con Edison's equity interest in Coram is consolidated in the financial statements. At December 31, 2016, net assets of the project were approximately $96 million.

Dispositions

Pike County Light & Power Company (Pike)

In October 2015, O&R entered into an agreement to sell Pike to Corning Natural Gas Holding Corporation (Corning). In August 2016, the sale was completed. O&R received cash consideration of $15 million for the sale. O&R has agreed to provide transition services to Corning for operations and customer support for a period of up to 18 months subsequent to the sale. In addition, O&R will continue to purchase and sell to Pike electric and gas commodity for three years. Pike has an option to extend the service for up to an additional three years. At September 30, 2015, O&R recorded an impairment charge of $5 million ($3 million, net of taxes), representing the difference between the carrying amount of Pike’s assets and the estimated sales proceeds. At December 31, 2015, Pike’s total assets and liabilities held for sale were $23 million and $5 million, respectively. There were no amounts outstanding at December 31, 2016.

Con Edison Solutions' Retail Electric Supply Business

In July 2016, Con Edison Solutions entered into an agreement to sell the assets of its retail electric supply business (including retail contracts, related derivative instruments, information systems, and accounts receivable) to a subsidiary of Exelon Corporation (Exelon). In September 2016, the sale was completed for cash consideration of $235 million, subject to working capital adjustments. The sale resulted in a gain of $104 million ($56 million, net of taxes), inclusive of a $65 million ($42 million, net of taxes) gain on derivative instruments. The tax effect of the sale includes $16 million ($10 million, net of federal tax) of state taxes related to a change in the apportionment of state income taxes. Con Edison Solutions has agreed to provide transition services to the Exelon subsidiary for operations and customer support through the end of 2017 during which period certain guarantees or other credit support provided by Con Edison in connection with the retail electric supply business may continue in effect. See Note H. At December 31, 2015, Con Edison Solutions' total assets and liabilities held for sale were $134 million and $84 million, respectively. There were no amounts outstanding at December 31, 2016.

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Schedule I - Condensed Financial Information

12 Months Ended

Dec. 31, 2016

Condensed Financial Information of Parent Company Only 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)	2016	2015	2014
Equity in earnings of subsidiaries	$1,254	$1,195	$1,101
Other income (deductions), net of taxes	32	27	19
Interest expense	(41)	(29)	(28)
Net Income	$1,245	$1,193	$1,092
Comprehensive Income	$1,252	$1,204	$1,072
Net Income Per Share – Basic	$4.15	$4.07	$3.73
Net Income Per Share – Diluted	$4.12	$4.05	$3.71
Dividends Declared Per Share	$2.68	$2.60	$2.52
Average Number Of Shares Outstanding—Basic (In Millions)	300.4	293.0	292.9
Average Number Of Shares Outstanding—Diluted (In Millions)	301.9	294.4	294.0

(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)	2016	2015	2014
Net Income	$1,245	$1,193	$1,092
Equity in earnings of subsidiaries	(1,254)	(1,195)	(1,101)
Dividends received from:
CECONY	744	872	712
O&R	43	81	40
Clean Energy Businesses	10	8	8
Change in Assets:
Special deposits	—	—	314
Income taxes receivable	87	58	(224)
Other – net	(152)	(382)	(199)
Net Cash Flows from Operating Activities	723	635	642
Investing Activities
Contributions to subsidiaries	(691)	(15)	(1)
Long term debt receivable from affiliated companies	(900)	—	—
Net Cash Flows Used in Investing Activities	(1,591)	(15)	(1)
Financing Activities
Net proceeds of short-term debt	(53)	162	101
Issuance of long-term debt	900	—	—
Retirement of long-term debt	(2)	(2)	(2)
Debt issuance costs	(5)	—	—
Issuance of common shares for stock plans, net of repurchases	51	1	(10)
Issuance of common shares - public offering	702	—	—
Common stock dividends	(763)	(733)	(739)
Net Cash Flows Used in Financing Activities	830	(572)	(650)
Net Change for the Period	(38)	48	(9)
Balance at Beginning of Period	51	3	12
Balance at End of Period	$13	$51	$3

(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)	2016	2015
Assets
Current Assets
Cash and temporary cash investments	$13	$51
Special deposits	1	1
Accounts receivable – other	—	4
Income taxes receivable	79	166
Accounts receivable from affiliated companies	702	517
Prepayments	24	34
Other current assets	18	17
Total Current Assets	837	790
Investments in subsidiaries	13,991	12,737
Goodwill	406	406
Deferred income tax	42	11
Long term debt receivable from affiliated companies	900	—
Other noncurrent assets (b)	16	7
Total Assets	$16,192	$13,951
Liabilities and Shareholders’ Equity
Current Liabilities
Long-term debt due within one year	$2	$2
Notes payable	384	437
Accounts Payable	1	—
Accounts payable to affiliated companies	288	146
Accrued taxes	7	—
Other current liabilities	14	10
Total Current Liabilities	696	595
Total Liabilities	696	595
Long-term debt (b)	1,198	304
Shareholders’ Equity
Common stock, including additional paid-in capital	5,887	5,062
Retained earnings	8,411	7,990
Total Shareholders’ Equity	14,298	13,052
Total Liabilities and Shareholders’ Equity	$16,192	$13,951

(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, 2016

Valuation and Qualifying Accounts [Abstract]

Schedule II - Valuation and Qualifying Accounts

Schedule II

Valuation and Qualifying Accounts

For the Years Ended December 31, 2016, 2015 and 2014

				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):
		2016	$96	$63		$—	$76	$83
		2015	$106	$77	—		$87	$96
		2014	$103	$98	—		$95	$106
CECONY	Allowance for uncollectible accounts (a):
		2016	$91	$57		$—	$70	$78
		2015	$98	$69	—		$76	$91
		2014	$95	$91	—		$88	$98

(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 (Policies)

12 Months Ended

Dec. 31, 2016

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 Q), as required. All intercompany balances and 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. The Utilities are receiving or being credited with a return on all of their regulatory assets for which a cash outflow has been made, and are paying or being charged with a return on all of their regulatory liabilities for which a cash inflow has been received. The Utilities’ regulatory assets and liabilities will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable state regulators.

Plant and Depreciation and Non-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 R.

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 4.7 percent, 4.4 percent and 1.6 percent for 2016, 2015 and 2014, respectively. The AFUDC rates for O&R were 3.5 percent, 0.4 percent and 2.6 percent for 2016, 2015 and 2014, 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 3.1 percent for 2016, 2015 and 2014. The average depreciation rates for O&R were 2.9 percent, 3.0 percent and 2.9 percent for 2016, 2015 and 2014, respectively.

The estimated lives for utility plant for CECONY range from 5 to 85 years for electric and 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 and gas storage. 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 range from 3 to 30 years.

Goodwill

Goodwill

Con Edison tests 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 two-step, quantitative goodwill impairment test. However, Con Edison has not elected to perform the qualitative assessment and exclusively applies the two-step quantitative approach. The first step of the goodwill impairment test compares the estimated fair value of a reporting unit with its carrying value, including goodwill. If the estimated fair value of a reporting unit exceeds its carrying value, goodwill of the reporting unit is considered not impaired. If the carrying value exceeds the estimated fair value of the reporting unit, the second step is performed to measure the amount of impairment loss, if any. The second step requires a calculation of the implied fair value of goodwill.

Long-Lived and Intangible Assets

Long-Lived and Intangible Assets

Con Edison evaluates the impairment of long-lived assets and intangible assets with definite lives, based on projections of undiscounted future cash flows, whenever events or changes in circumstances indicate that the carrying amounts of such assets may not be recoverable. In the event an evaluation indicates that such cash flows cannot be expected to be sufficient to fully recover the assets, the assets are written down to their estimated fair value.

Revenues

Revenues

The Utilities recognize and, until the sale of its retail electric supply business in September 2016 (see Note U), Con Edison Solutions recognized revenues for energy service on a monthly billing cycle basis. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers. The Utilities accrue and Con Edison Solutions accrued revenues at the end of each month for estimated energy service not yet billed to customers.

CECONY’s electric and gas rate plans and O&R’s New York electric and gas rate plans each contain a revenue decoupling mechanism under which the company’s actual energy delivery revenues are compared 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.

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

Investments consist primarily of the investments of Con Edison Transmission and the Clean Energy Businesses that are accounted for under the equity method and the fair value of the Utilities’ supplemental retirement income plan and deferred income plan assets.

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. Generally, O&R also defers such difference pursuant to its 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 tax liability, the Utilities have established regulatory assets for the net revenue requirements to be recovered from customers for the related future tax expense. See Notes B and L. In 1993, the NYSPSC issued a Policy Statement approving accounting procedures consistent with accounting rules for income taxes and providing assurances that these future increases in taxes will be recoverable in rates. See Note L.

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

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

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

Reclassification

Reclassification

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

Earnings Per Common Share

Earnings Per Common Share

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

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

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 May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board jointly issued a revenue recognition standard that will supersede the revenue recognition requirements within Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. Amendments were issued subsequently to clarify key areas including principal/agent considerations, performance obligations, licensing, sales taxes, noncash consideration, and contracts. The new standard is effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for reporting periods beginning after December 15, 2016, however, the Companies plan to adopt the new standard for reporting periods beginning after December 15, 2017.

Under the new standard, companies may use either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a modified retrospective approach with the cumulative effect of initially adopting ASU 2014-09 recognized at the date of adoption (which includes additional footnote disclosures). The Companies anticipate using the modified retrospective approach.

The Companies are currently in the process of evaluating the impact of the new standard on their various revenue streams. The majority of the Companies’ sales are derived from tariffs to provide electric, gas, and steam service to customers. For such tariffs, the Companies expect that the revenue from contracts with the customer under ASU 2014-09 will be equivalent to the electricity, gas, or steam supplied in that period which is consistent with current practice. Consequently, the Companies do not anticipate that the new standard will significantly impact the amount and/or timing of such revenues. The Companies continue to review the potential impacts of other revenue at the Utilities and the Clean Energy Businesses on the Companies' financial position, results of operations and liquidity as well as the additional disclosures required under the new standard.

In January 2016, the FASB issued amendments on certain aspects of recognition, measurement, presentation, and disclosure of financial instruments through ASU No. 2016-01, “Financial Instruments (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities.” The amendments require changes to the accounting for equity investments, the presentation and disclosure requirements for financial liabilities under the fair value option, and the presentation and disclosure requirements for financial instruments. In addition, clarification was provided related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for portions of the standard. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. Based on the existing portfolio of leases at implementation, for leases currently classified as operating leases, the Companies expect to recognize on the statements of financial position right-of-use assets and lease liabilities. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ results of operations and liquidity.

In March 2016, the FASB issued amendments to the guidance for Derivatives and Hedging accounting through ASU 2016-05, “Derivatives and Hedging (Topic 815): Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships." The amendments clarify that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require discontinuation of the application of hedge accounting. The amendments in this update are effective for financial statements issued for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to clarify the guidance for assessing whether contingent call (put) options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts through ASU No. 2016-06, “Derivatives & Hedging (Topic 815): Contingent Put and Call Options in Debt Instruments.” An entity performing the assessment under the amendments is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for financial statements issued for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to eliminate the requirement to retroactively adopt the equity method of accounting when a company increases its level of ownership or degree of influence over an investment through ASU No. 2016-07, “Investments-Equity Method and Joint Ventures (Topic 323): Simplifying the Transition to the Equity Method of Accounting.” The amendments require that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in Accumulated Other Comprehensive Income at the date the investment qualifies for the equity method. The amendments are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In March 2016, the FASB issued amendments to simplify several aspects of the accounting for share-based payment transactions through ASU No. 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The amendments simplify areas such as income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. The amendments are effective for reporting periods beginning after December 15, 2016. The company elected to early adopt this standard as permitted, and it did not have a material impact on the Companies’ financial position, results of operations and liquidity.

In May 2016, the FASB issued amendments to the guidance on revenue recognition and derivatives and hedging through ASU 2016-11, “Revenue Recognition (Topic 605) and Derivatives and Hedging (Topic 815): Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting (SEC Update).” The amendment rescinds certain SEC guidance superseded by the newly issued revenue recognition and hedging guidance (ASU 2014-09 and 2014-16 respectively). The amendments will be effective upon adoption of ASU 2014-09 and 2014-16. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In June 2016, the FASB issued amendments to the guidance for recognition of credit losses for financial instruments through ASU 2016-13, “Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The amendment replaces the incurred loss impairment methodology which involved delayed recognition of credit losses. As the updated guidance now requires credit losses to be recognized when expected rather than when incurred, a broader range of reasonable and supportable information must be considered in developing the credit loss estimates. This includes financial instruments that are valued at amortized cost and available for sale. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted for reporting periods beginning after December 15, 2018. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In August 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments (a consensus of the Emerging Issues Task Force).” The amendment specifies the classification and presentation of certain cash flow items to reduce diversity in practice. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In October 2016, the FASB issued amendments to the guidance for Income Taxes through ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory).” The amendment clarifies the tax treatment of intra-entity transfers of assets other than inventory. The updated guidance requires entities to recognize the income tax consequences of an intra-entity transfer of assets other than inventory when the transfer occurs. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In October 2016, the FASB issued amendments to the guidance for Consolidation through ASU 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties That Are under Common Control.” The amendments in this update change how a single decision maker of a VIE will consider its indirect interests in a VIE held by related parties under common control when performing the primary beneficiary analysis. If a single decision maker and its related parties are under common control, the single decision maker must evaluate indirect interests on a proportionate basis when evaluating whether it is a primary beneficiary of the VIE. The guidance does not change the characteristics of a primary beneficiary under GAAP but has amended the considerations in the evaluation of determining the primary beneficiary of a VIE under common control. For public entities, the amendments are effective for reporting periods beginning after December 15, 2016. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In November 2016, the FASB issued amendments to the guidance for the Statement of Cash Flows through ASU 2016-18, “Update 2016-18-Statement of Cash Flows (Topic 230): Restricted Cash (a consensus of the FASB Emerging Issues Task Force).” The amendments in this update clarify the presentation of changes in restricted cash and restricted cash equivalents in the statement of cash flows. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In January 2017, the FASB issued amendments to the guidance for Business Combinations through ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business.” The amendments in this update clarify the definition of a business and provide guidance on evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In January 2017, the FASB issued amendments to the guidance for the subsequent measurement of goodwill through ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The amendments in this update simplify goodwill impairment testing by eliminating Step 2 of the goodwill impairment test wherein an entity has to compute the implied fair value of goodwill by performing procedures to determine the fair value of its assets and liabilities. Under the new guidance, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value up to the total amount of goodwill allocated to that reporting unit. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

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Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2016

Accounting Policies [Abstract]

Capitalized Cost of Utility Plant

At December 31, 2016 and 2015, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Electric
Generation	$479	$459	$479	$459
Transmission	3,184	3,045	2,963	2,833
Distribution	18,150	17,244	17,234	16,394
Gas (a)	6,285	5,698	5,749	5,196
Steam	1,882	1,849	1,882	1,849
General	1,816	1,758	1,639	1,592
Held for future use	74	77	65	65
Construction work in progress	1,175	1,003	1,104	922
Net Utility Plant	$33,045	$31,133	$31,115	$29,310

(a) Primarily distribution.

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)	2016	2015	2014
Con Edison	$336	$354	$365
CECONY	316	331	343

Schedule of Equity Method Investments

The following investment assets are included in the Companies' consolidated balance sheets at December 31, 2016 and 2015:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015		2016		2015
CET Gas investment in Stagecoach Gas Services, LLC (a)	$992		$—		$—		$—
Con Edison Development equity method investments (b)	488	574		—		—
Supplemental retirement income plan assets (c)	273	243		246		221
Deferred income plan assets	60	55		60		55
CET Electric investment in New York Transco, LLC	51	3		—		—
CET Gas investment in Mountain Valley Pipeline, LLC	48	—		—		—
Other	9	9		9		10
Total investments	$1,921	$884		$315		$286

(a) See Note U.

(b) See Note Q.

(c) See Note E.

Research and Development Costs

Research and development costs were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
Con Edison	$24	$23	$22
CECONY	22	22	20

Basic and Diluted Earnings Per Share

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

	For the Years Ended December 31,
(Millions of Dollars, except per share amounts/Shares in Millions)	2016	2015	2014
Net income	$1,245	$1,193	$1,092
Weighted average common shares outstanding – basic	300.4	293.0	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.5	1.4	1.1
Adjusted weighted average common shares outstanding – diluted	301.9	294.4	294.0
Net Income per common share – basic	$4.15	$4.07	$3.73
Net Income per common share – diluted	$4.12	$4.05	$3.71

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, 2014 (a)	$(45)	$(11)
OCI before reclassifications, net of tax of $(3) for Con Edison	5	1
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(4) and $(1) for Con Edison and CECONY, respectively(a)(b)	6	1
Total OCI, net of taxes, at December 31, 2015	11	2
Accumulated OCI, net of taxes, at December 31, 2015 (a)	$(34)	$(9)
OCI before reclassifications, net of tax of $(1) for Con Edison and CECONY	2	1
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(3) and $(1) for Con Edison and CECONY, respectively(a)(b)	5	1
Total OCI, net of taxes, at December 31, 2016	7	2
Accumulated OCI, net of taxes, at December 31, 2016 (a)	$(27)	$(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 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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Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2016

Public Utilities, General Disclosures [Line Items]

Schedule of Regulatory Assets

Regulatory assets and liabilities at December 31, 2016 and 2015 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$2,874	$3,876	$2,730	$3,697
Future income tax	2,439	2,350	2,325	2,232
Environmental remediation costs	823	904	711	800
Revenue taxes	295	253	280	240
Deferred storm costs	56	185	3	110
Deferred derivative losses	48	50	42	46
Unamortized loss on reacquired debt	43	50	41	48
Recoverable energy costs	42	16	38	15
Pension and other postretirement benefits deferrals	38	45	7	16
O&R property tax reconciliation	37	46	—	—
Surcharge for New York State assessment	28	44	26	40
Preferred stock redemption	25	26	25	26
Net electric deferrals	24	44	24	44
O&R transition bond charges	15	21	—	—
Workers’ compensation	13	11	13	11
Other	224	175	208	157
Regulatory assets – noncurrent	7,024	8,096	6,473	7,482
Deferred derivative losses	91	113	86	103
Recoverable energy costs	9	19	4	18
Regulatory assets – current	100	132	90	121
Total Regulatory Assets	$7,124	$8,228	$6,563	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$755	$676	$641	$570
Pension and other postretirement benefit deferrals	193	76	162	46
Property tax reconciliation	178	303	178	303
Net unbilled revenue deferrals	145	109	145	109
Prudence proceeding	95	99	95	99
Carrying charges on repair allowance and bonus depreciation	68	49	67	48
New York State income tax rate change	61	75	60	72
Unrecognized other postretirement costs	60	28	60	28
Variable-rate tax-exempt debt - cost rate reconciliation	55	70	48	60
Base rate change deferrals	40	128	40	128
Earnings sharing - electric, gas and steam	39	80	28	80
Net utility plant reconciliations	16	32	15	31
Property tax refunds	1	44	1	44
World Trade Center settlement proceeds	—	21	—	21
Other	199	187	172	150
Regulatory liabilities – noncurrent	1,905	1,977	1,712	1,789
Revenue decoupling mechanism	71	45	61	45
Refundable energy costs	29	64	5	33
Deferred derivative gains	28	6	24	6
Regulatory liabilities—current	128	115	90	84
Total Regulatory Liabilities	$2,033	$2,092	$1,802	$1,873

Schedule of Regulatory Liabilities

Regulatory assets and liabilities at December 31, 2016 and 2015 were comprised of the following items:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Regulatory assets
Unrecognized pension and other postretirement costs	$2,874	$3,876	$2,730	$3,697
Future income tax	2,439	2,350	2,325	2,232
Environmental remediation costs	823	904	711	800
Revenue taxes	295	253	280	240
Deferred storm costs	56	185	3	110
Deferred derivative losses	48	50	42	46
Unamortized loss on reacquired debt	43	50	41	48
Recoverable energy costs	42	16	38	15
Pension and other postretirement benefits deferrals	38	45	7	16
O&R property tax reconciliation	37	46	—	—
Surcharge for New York State assessment	28	44	26	40
Preferred stock redemption	25	26	25	26
Net electric deferrals	24	44	24	44
O&R transition bond charges	15	21	—	—
Workers’ compensation	13	11	13	11
Other	224	175	208	157
Regulatory assets – noncurrent	7,024	8,096	6,473	7,482
Deferred derivative losses	91	113	86	103
Recoverable energy costs	9	19	4	18
Regulatory assets – current	100	132	90	121
Total Regulatory Assets	$7,124	$8,228	$6,563	$7,603
Regulatory liabilities
Allowance for cost of removal less salvage	$755	$676	$641	$570
Pension and other postretirement benefit deferrals	193	76	162	46
Property tax reconciliation	178	303	178	303
Net unbilled revenue deferrals	145	109	145	109
Prudence proceeding	95	99	95	99
Carrying charges on repair allowance and bonus depreciation	68	49	67	48
New York State income tax rate change	61	75	60	72
Unrecognized other postretirement costs	60	28	60	28
Variable-rate tax-exempt debt - cost rate reconciliation	55	70	48	60
Base rate change deferrals	40	128	40	128
Earnings sharing - electric, gas and steam	39	80	28	80
Net utility plant reconciliations	16	32	15	31
Property tax refunds	1	44	1	44
World Trade Center settlement proceeds	—	21	—	21
Other	199	187	172	150
Regulatory liabilities – noncurrent	1,905	1,977	1,712	1,789
Revenue decoupling mechanism	71	45	61	45
Refundable energy costs	29	64	5	33
Deferred derivative gains	28	6	24	6
Regulatory liabilities—current	128	115	90	84
Total Regulatory Liabilities	$2,033	$2,092	$1,802	$1,873

Rockland Electric Company (RECO)

Public Utilities, General Disclosures [Line Items]

Summary of Utilities Rate Plans

RECO
Effective period	May 2010 – July 2014	August 2014 – July 2015 (a)
Base rate changes	Yr. 1 – $9.8 million	Yr. 1 – $13.0 million
Amortization to income of net regulatory (assets) and liabilities	$(3.9) million over four years and $(4.9) million of deferred storm costs over five years	$0.4 million over three years and $(25.6) million of deferred storm costs 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	$148.6 million	$172.2 million
Weighted average cost of capital (after-tax)	8.21 percent	7.83 percent
Authorized return on common equity	10.3 percent	9.75 percent
Cost of long-term debt	6.16 percent	5.89 percent
Common equity ratio	50 percent	50 percent

(a) In January 2016, the NJBPU approved RECO’s plan for a 3-year, $15.7 million electric system storm hardening capital program, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge until a new rate plan is approved that reflects the costs.

Electric | CECONY

Public Utilities, General Disclosures [Line Items]

Summary of Utilities Rate Plans

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

CECONY – Electric
Effective period	January 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(76.2) million (a) Yr. 2 – $124.0 million (a) Yr. 3 – None	Yr. 1 - $195 million (b) Yr. 2 - $155 million (b) Yr. 3 - $155 million (b)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 and 2 – $(37) million (c) Yr. 3 - $123 million (c)	Yr. 1 - $84 million Yr. 2 - $83 million Yr. 3 - $69 million
Other revenue sources	Retention of $90 million of annual transmission congestion revenues.	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
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred for customer benefit $146 million, $98 million and $101 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs (d)	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties (up to $400 million annually) if certain performance targets are not met. In 2014, the company recorded a $5 million negative revenue adjustment. In 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $376 million Yr. 2 - $383 million Yr. 3 - $395 million.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $57 million, $26 million and $68 million of net regulatory liabilities, respectively (e).	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)
Net utility plant reconciliations	Target levels reflected in rates were: Transmission and distribution: Yr. 1 – $16,869 million Yr. 2 – $17,401 million Yr. 3 – $17,929 million Storm hardening: Yr. 1 – $89 million; Yr. 2 – $177 million; Yr. 3 – $268 million Other: Yr. 1 – $2,034 million; Yr. 2 – $2,102 million; Yr. 3 – $2,069 million The company deferred $6 million and $17 million as a regulatory liability in 2014 and 2015, respectively. In 2016, $9 million was deferred as a regulatory asset.	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
Average rate base	Yr. 1 – $17,323 million Yr. 2 – $18,113 million Yr. 3 – $18,282 million	Yr. 1 - $18,902 million Yr. 2 - $19,530 million Yr. 3 - $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.05 percent Yr. 2 – 7.08 percent Yr. 3 – 6.91 percent	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	Yrs. 1 and 2 – 9.2 percent Yr. 3 – 9.0 percent	9.0 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.8 percent for Yrs. 1 and 2 and 9.6 percent for Yr. 3 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 $44.4 million and $6.5 million above the threshold for 2015 and 2016, respectively.	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.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.09 percent	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $30 million regulatory liability at December 31, 2015; this amount has been amortized to $0 at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's electric rate plan for January 2017 through December 2019. The electric base rate increases are 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 are being 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 ten-year period, including the overall pre-tax rate of return on such costs.

(c) Amounts reflect annual amortization of $107 million of the regulatory asset for deferred Superstorm Sandy and other major storm costs. The costs recoverable from customers were reduced by $4 million. The costs are no longer subject to NYSPSC staff review and the recovery of the costs is no longer subject to refund. In 2016, an additional $123 million of net regulatory liabilities were amortized to income.

(d) For transmission service provided pursuant to the open access transmission tariff of PJM Interconnection LLC (PJM), unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. Starting in January 2014, PJM submitted to the FERC a series of requests that substantially increase the charges for the transmission service. CECONY has challenged each of these requests. To date, FERC has rejected all but one of CECONY’s protests. In April 2016, CECONY notified PJM that it will not be exercising its option to continue the service beyond April 2017. CECONY is continuing to challenge FERC’s approval of the increased charges that are being incurred through the end of the current contract term. In June 2015 and May 2016, CECONY filed appeals of certain FERC decisions with the U.S. Court of Appeals.

(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 (5.0, 7.5 or 10.0 basis points, depending on the year).

(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 of 30 percent of the amount reflected in rates.

(g) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers.

Electric | O&R

Public Utilities, General Disclosures [Line Items]

Summary of Utilities Rate Plans

O&R New York – Electric
Effective period	July 2012 – June 2015	November 2015 - October 2017
Base rate changes	Yr. 1 – $19.4 million Yr. 2 – $8.8 million Yr. 3 – $15.2 million	Yr. 1 – $9.3 million Yr. 2 – $8.8 million
Amortizations to income of net regulatory (assets) and liabilities	$(32.2) million over three years	Yr. 1 – $(8.5) million (a) Yr. 2 – $(9.4) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred for the customer’s benefit $2.6 million, $3.2 million and $(3.4) million, respectively.	In 2015 and 2016, the company deferred for the customer’s benefit an immaterial amount and $6.3 million as regulatory liabilities, respectively.
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential penalties (up to $3 million annually) if certain customer service and system reliability performance targets are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (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, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase/(decrease) to regulatory assets, respectively.	In 2015 and 2016, the company deferred $0.3 million and $7.4 million as net decreases to regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Yr. 1 – $678 million; Yr. 2- $704 million; Yr. 3 – $753 million The company increased its regulatory liability by $4.2 million in 2012. The company reduced its regulatory liability by $1.1 million and $2.3 million in 2013 and 2014, respectively.	Target levels reflected in rates are: Yr. 1 – $928 million (b) Yr. 2 – $970 million (b) The company increased/(reduced) its regulatory asset by $2.2 million and $(1.9) million in 2015 and 2016, respectively.
Average rate base	Yr. 1 – $671 million Yr. 2 – $708 million Yr. 3 – $759 million	Yr. 1 – $763 million Yr. 2 – $805 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.61 percent Yr. 2 – 7.65 percent Yr. 3 – 7.48 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent
Authorized return on common equity	Yr. 1 – 9.4 percent Yr. 2 – 9.5 percent Yr. 3 – 9.6 percent	9.0 percent
Earnings sharing	The company recorded a regulatory liability of $1 million for earnings above the sharing threshold under the rate plan as of December 31, 2014.	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 above the threshold for 2016.
Cost of long-term debt	Yr. 1 – 6.07 percent Yr. 2 – 6.07 percent Yr. 3 – 5.64 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a five 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.

(b) 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.

Gas | CECONY

Public Utilities, General Disclosures [Line Items]

Summary of Utilities Rate Plans

CECONY – Gas
Effective period	January 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(54.6) million (a) Yr. 2 – $38.6 million (a) Yr. 3 – $56.8 million (a)	Yr. 1 - $(5) million (b) Yr. 2 - $92 million (b) Yr. 3 - $90 million (b)
Amortizations to income of net regulatory (assets) and liabilities	$4 million over three years	Yr. 1 - $39 million Yr. 2 - $37 million Yr. 3 - $36 million
Other revenue sources	Retention of revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. The company retained $70 million, $66 million and $65 million of such revenues in 2014, 2015 and 2016, respectively.	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.
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred $28 million, $54 million and $71 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $33 million in 2014, $44 million in 2015, and $56 million in 2016) if certain gas performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 - $68 million Yr. 2 - $75 million Yr. 3 - $83 million.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $38 million, $11 million, and $32 million of net regulatory liabilities, respectively. (c)	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates.(d)
Net utility plant reconciliations	Target levels reflected in rates were: Gas delivery Yr. 1 – $3,899 million; Yr. 2 – $4,258 million; Yr. 3 – $4,698 million Storm hardening: Yr. 1 – $3 million; Yr. 2 – $8 million; Yr. 3 – $30 million In 2015 $1 million was deferred as a regulatory liability. In 2014 and 2016 the company deferred an immaterial amount.	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
Average rate base	Yr. 1 – $3,521 million Yr. 2 – $3,863 million Yr. 3 – $4,236 million	Yr. 1 - $4,841 million Yr. 2 - $5,395 million Yr. 3 - $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent	Yr. 1 - 6.82 percent Yr. 2 - 6.80 percent Yr. 3 - 6.73 percent
Authorized return on common equity	9.3 percent	9.0 percent
Earnings sharing	Most 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, 2015 and 2016, the company had no earnings above the threshold.	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.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent	Yr. 1 - 4.93 percent Yr. 2 - 4.88 percent Yr. 3 - 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $32 million regulatory liability at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's gas rate plan for January 2017 through December 2019. The gas base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(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) See footnotes (e), (f) and (g) to the table under "CECONY - Electric" above.

Gas | O&R

Public Utilities, General Disclosures [Line Items]

Summary of Utilities Rate Plans

O&R New York – Gas
Effective period	November 2009 – December 2014	November 2015 – October 2018
Base rate changes	Yr. 1 – $9 million Yr. 2 – $9 million Yr. 3 – $4.6 million Yr. 3 – $4.3 million collected through a surcharge Yr. 4 – None Yr. 5 – None	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge
Amortization to income of net regulatory (assets) and liabilities	$(2) million over three years	Yr. 1 – $(1.7) million (a) Yr. 2 – $(2.1) million (a) Yr. 3 – $(2.5) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred $4.7 million, $0.7 million and $(0.1) million of regulatory liabilities, respectively.	In 2015 and 2016, the company deferred $0.8 million regulatory assets and $6.2 million of regulatory liabilities, respectively.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $1.4 million annually) if certain operations and customer service requirements are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $5.8 million in Yr. 3) if certain performance targets are not met. In 2015 and 2016, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $0.7 million, $8.3 million and $8.3 million as net regulatory assets, respectively.	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively.
Net utility plant reconciliations	The company deferred $0.7 million in 2012 as a regulatory asset and no deferrals were recorded for 2013 or 2014.	Target levels reflected in rates are: Yr. 1 – $492 million (b) Yr. 2 – $518 million (b) Yr. 3 – $546 million (b) No deferral was recorded for 2015 and an immaterial amount was recorded as a regulatory liability in 2016.
Average rate base	Yr. 1 – $280 million Yr. 2 – $296 million Yr. 3 – $309 million	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million
Weighted average cost of capital (after-tax)	8.49 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent
Authorized return on common equity	10.4 percent	9.0 percent
Earnings sharing	Earnings above an annual earnings threshold of 11.4 percent are to be applied to reduce regulatory assets. In 2012, 2013 and 2014, 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. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million above the threshold for 2016.
Cost of long-term debt	6.81 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) 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.

(b) 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.

Steam | CECONY

Public Utilities, General Disclosures [Line Items]

Summary of Utilities Rate Plans

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
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 penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015 and 2016, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets and $8 million of net regulatory liabilities, 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.
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
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.
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.

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Capitalization (Tables)

12 Months Ended

Dec. 31, 2016

Debt Disclosure [Abstract]

Schedule of Long-Term Debt Maturities

Long-term debt maturing in the period 2017-2021 is as follows:

(Millions of Dollars)	Con Edison	CECONY
2017	$39		$—
2018	1,688	1,200
2019	574	475
2020	388	350
2021	540	—

Carrying Amounts and Fair Values of Long-Term Debt

The carrying amounts and fair values of long-term debt at December 31, 2016 and 2015 are:

(Millions of Dollars)	2016		2015
Long-Term Debt (including current portion)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$14,774	$16,093	$12,745	$13,856
CECONY	$12,073	$13,268	$11,437	$12,427

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Pension Benefits (Tables) - Pension Benefits

12 Months Ended

Dec. 31, 2016

Defined Benefit Plan Disclosure [Line Items]

Total Periodic Benefit Costs

The components of the Companies’ total periodic benefit costs for 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Service cost – including administrative expenses	$275	$297	$227	$258	$279	$211
Interest cost on projected benefit obligation	596	575	572	559	538	536
Expected return on plan assets	(947)	(886)	(832)	(898)	(840)	(789)
Recognition of net actuarial loss	596	775	618	565	734	586
Recognition of prior service costs	4	4	4	2	2	2
NET PERIODIC BENEFIT COST	$524	$765	$589	$486	$713	$546
Amortization of regulatory asset (a)	—	1	2	—	1	2
TOTAL PERIODIC BENEFIT COST	$524	$766	$591	$486	$714	$548
Cost capitalized	(214)	(301)	(225)	(203)	(285)	(212)
Reconciliation to rate level	54	(74)	118	58	(74)	108
Cost charged to operating expenses	$364	$391	$484	$341	$355	$444

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

Schedule of Funded Status

The funded status at December 31, 2016, 2015 and 2014 was as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$14,377	$15,081	$12,197	$13,482	$14,137	$11,429
Service cost – excluding administrative expenses	271	293	221	254	274	206
Interest cost on projected benefit obligation	596	575	572	559	538	536
Net actuarial (gain)/loss	(302)	(996)	2,641	(282)	(931)	2,484
Plan amendments	(256)	—	6	(259)	—	—
Benefits paid	(591)	(576)	(556)	(551)	(536)	(518)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	$14,095	$14,377	$15,081	$13,203	$13,482	$14,137
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$11,759	$11,495	$10,755	$11,141	$10,897	$10,197
Actual return on plan assets	829	126	752	787	118	715
Employer contributions	508	750	578	469	697	535
Benefits paid	(591)	(576)	(556)	(551)	(536)	(518)
Administrative expenses	(33)	(36)	(34)	(31)	(35)	(32)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$12,472	$11,759	$11,495	$11,815	$11,141	$10,897
FUNDED STATUS	$(1,623)	$(2,618)	$(3,586)	$(1,388)	$(2,341)	$(3,240)
Unrecognized net loss	$3,157	$3,909	$4,888	$2,995	$3,704	$4,616
Unrecognized prior service costs	(244)	16	20	(258)	3	4
Accumulated benefit obligation	12,655	12,909	13,454	11,806	12,055	12,553

Schedule of Assumptions

The actuarial assumptions were as follows:

	2016		2015		2014
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount rate	4.25	%	4.25	%	3.90	%
Rate of compensation increase
CECONY	4.25	%	4.25	%	4.25	%
O&R	4.00	%	4.00	%	4.00	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate	4.25	%	3.90	%	4.80	%
Expected return on plan assets	7.80	%	7.80	%	8.00	%
Rate of compensation increase
CECONY	4.25	%	4.25	%	4.35	%
O&R	4.00	%	4.00	%	4.25	%

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)	2017	2018	2019	2020	2021	2022-2026
Con Edison	$702	$719	$730	$745	$758	$3,990
CECONY	653	670	679	693	705	3,716

Schedule of Plan Assets Allocations

The asset allocations for the pension plan at the end of 2016, 2015 and 2014, and the target allocation for 2017 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2017	2016		2015		2014
Equity Securities	52% - 64%	58	%	57	%	58	%
Debt Securities	28% - 38%	33	%	33	%	32	%
Real Estate	7% - 11%	9	%	10	%	10	%
Total	100%	100	%	100	%	100	%

Schedule of Fair Value of Plan Assets

The fair values of the pension plan assets at December 31, 2015 by asset category are as follows:

(Millions of Dollars)	Level 1	Level 2		Total
Investments within the fair value hierarchy
U.S. Equity (a)	$3,106		$—	$3,106
International Equity (b)	2,874	346		3,220
U.S. Government Issued Debt (c)	—	2,222		2,222
Corporate Bonds Debt (d)	—	1,356		1,356
Structured Assets Debt (e)	—	1		1
Other Fixed Income Debt (f)	—	170		170
Cash and Cash Equivalents (g)	115	414		529
Futures (h)	161	132		293
Total investments within the fair value hierarchy	$6,256	$4,641		$10,897
Investments measured at NAV per share (n)
Private Equity (i)				170
Real Estate (j)				1,248
Hedge Funds (k)				233
Total investments valued using NAV per share				$1,651
Funds for retiree health benefits (l)	(162)	(120)		(282)
Funds for retiree health benefits measured at NAV per share (l)(n)				(43)
Total funds for retiree health benefits				$(325)
Investments (excluding funds for retiree health benefits)	$6,094	$4,521		$12,223
Pending activities (m)				(464)
Total fair value of plan net assets				$11,759

(a) - (n) Reference is made to footnotes (a) through (n) in the above table of pension plan assets at December 31, 2016 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)	2016	2015	2014
Con Edison	$36	$34	$32
CECONY	32	29	27

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Other Postretirement Benefits (Tables) - Other Postretirement Benefits

12 Months Ended

Dec. 31, 2016

Defined Benefit Plan Disclosure [Line Items]

Net Periodic Benefit Costs

The components of the Companies’ total periodic postretirement benefit costs for 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Service cost	$18	$20	$19	$13	$15	$15
Interest cost on accumulated other postretirement benefit obligation	48	51	60	40	43	52
Expected return on plan assets	(77)	(78)	(77)	(67)	(68)	(68)
Recognition of net actuarial loss	5	31	57	3	28	51
Recognition of prior service cost	(20)	(20)	(19)	(14)	(14)	(15)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST	$(26)	$4	$40	$(25)	$4	$35
Cost capitalized	11	(2)	(15)	10	(2)	(14)
Reconciliation to rate level	22	14	10	22	6	2
Cost charged to operating expenses	$7	$16	$35	$7	$8	$23

Schedule of Funded Status

The funded status of the programs at December 31, 2016, 2015 and 2014 were as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
CHANGE IN BENEFIT OBLIGATION
Benefit obligation at beginning of year	$1,287	$1,411	$1,395	$1,093	$1,203	$1,198
Service cost	18	20	19	13	15	15
Interest cost on accumulated postretirement benefit obligation	48	51	60	40	43	52
Amendments	—	—	(12)	—	—	—
Net actuarial loss/(gain)	(57)	(103)	47	(52)	(85)	28
Benefits paid and administrative expenses	(134)	(127)	(134)	(122)	(117)	(125)
Participant contributions	36	35	36	35	34	35
BENEFIT OBLIGATION AT END OF YEAR	$1,198	$1,287	$1,411	$1,007	$1,093	$1,203
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	$994	$1,084	$1,113	$870	$950	$977
Actual return on plan assets	60	(6)	59	52	(4)	54
Employer contributions	7	6	7	7	6	7
EGWP payments	35	28	12	33	26	11
Participant contributions	36	35	36	35	34	35
Benefits paid	(157)	(153)	(143)	(146)	(142)	(134)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	$975	$994	$1,084	$851	$870	$950
FUNDED STATUS	$(223)	$(293)	$(327)	$(156)	$(223)	$(253)
Unrecognized net loss/(gain)	$(24)	$28	$78	$(42)	$4	$45
Unrecognized prior service costs	(31)	(51)	(71)	(18)	(32)	(46)

Schedule of Actuarial Assumptions

The actuarial assumptions were as follows:

	2016		2015		2014
Weighted-average assumptions used to determine benefit obligations at December 31:
Discount Rate
CECONY	4.00	%	4.05	%	3.75	%
O&R	4.20	%	4.20	%	3.85	%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount Rate
CECONY	4.05	%	3.75	%	4.50	%
O&R	4.20	%	3.85	%	4.75	%
Expected Return on Plan Assets	7.00	%	7.75	%	7.75	%

Schedule of Change of Assumed Health Care Cost Trend Rate

A one-percentage point change in the assumed health care cost trend rate would have the following effects at December 31, 2016:

	Con Edison		CECONY
	1-Percentage-Point
(Millions of Dollars)	Increase	Decrease	Increase	Decrease
Effect on accumulated other postretirement benefit obligation	$(4)	$26	$(24)	$41
Effect on service cost and interest cost components for 2016	1	—	(1)	1

Schedule of Expected Benefit Payments

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

(Millions of Dollars)	2017	2018	2019	2020	2021	2022-2026
Con Edison	$86	$85	$83	$80	$78	$375
CECONY	77	75	73	70	68	322

Schedule of Plan Assets Allocations

The asset allocations for CECONY’s other postretirement benefit plans at the end of 2016, 2015 and 2014, and the target allocation for 2017 are as follows:

	Target Allocation Range	Plan Assets at December 31,
Asset Category	2017	2016		2015		2014
Equity Securities	57%-73%	60	%	59	%	59	%
Debt Securities	26%-44%	40	%	41	%	41	%
Total	100%	100	%	100	%	100	%

Schedule of Fair Value of Plan Assets

The fair values of the plan assets at December 31, 2016 by asset category as defined by the accounting rules for fair value measurements (see Note P) are as follows:

(Millions of Dollars)	Level 1		Level 2	Total
Equity (a)		$—	$391	$391
Other Fixed Income Debt (b)	—		250	250
Cash and Cash Equivalents (c)	—		13	13
Total investments		$—	$654	$654
Funds for retiree health benefits (d)	165		105	270
Investments (including funds for retiree health benefits)	$165		$759	$924
Funds for retiree health benefits measured at net asset value (d)(e)				37
Pending activities (f)				14
Total fair value of plan net assets				$975

(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 Barclays Capital Aggregate 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, 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. See Note E.

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

The fair values of the plan assets at December 31, 2015 by asset category (see Note P) are as follows:

(Millions of Dollars)	Level 1		Level 2	Total
Equity (a)		$—	$393	$393
Other Fixed Income Debt (b)	—		260	260
Cash and Cash Equivalents (c)	—		7	7
Total investments		$—	$660	$660
Funds for retiree health benefits (d)	162		120	282
Investments (including funds for retiree health benefits)	$162		$780	$942
Funds for retiree health benefits measured at net asset value (d)(e)				43
Pending activities (f)				9
Total fair value of plan net assets				$994

(a) - (f) Reference is made to footnotes (a) through (f) in the above table of other postretirement benefit plan assets at December 31, 2016 by asset category.

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Environmental Matters (Tables)

12 Months Ended

Dec. 31, 2016

Environmental Remediation Obligations [Abstract]

Accrued Liabilities and Regulatory Assets

The accrued liabilities and regulatory assets related to Superfund Sites at December 31, 2016 and 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued Liabilities:
Manufactured gas plant sites	$664	$679	$567	$579
Other Superfund Sites	89	86	88	86
Total	$753	$765	$655	$665
Regulatory assets	$823	$904	$711	$800

Environmental Remediation Costs

Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites at December 31, 2016 and 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Remediation costs incurred	$34	$37	$21	$34
Insurance recoveries received (a)	1	—	1	—

(a) Reduced amount deferred for recovery from customers

Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at December 31, 2016 and 2015 were as follows:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$88	$86	$83	$81
Regulatory assets – workers’ compensation	$13	$11	$13	$11

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Other Material Contingencies (Tables)

12 Months Ended

Dec. 31, 2016

Commitments and Contingencies Disclosure [Abstract]

Summary of Total Guarantees

A summary, by type and term, of Con Edison’s total guarantees at December 31, 2016 is as follows:

Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$435	$613		$—	$1,048
Energy transactions	603	35	98		736
Renewable electric production projects	439	—	19		458
Other	128	—	—		128
Total	$1,605	$648	$117		$2,370

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Electricity Purchase Agreements (Tables)

12 Months Ended

Dec. 31, 2016

Regulated Operations [Abstract]

Summary of Significant Terms of Electricity Purchase Agreements

At December 31, 2016, the significant terms of the electricity purchase agreements with non-utility generators were as follows:

Facility	Equity Owner	Plant Output (MW)	Contracted Output (MW)	Contract Start Date	Contract Term (Years)
Brooklyn Navy Yard	Brooklyn Navy Yard Cogeneration Partners, LP	322	293	November 1996	40
Linden Cogeneration	Cogen Technologies Linden Venture, LP	974	630	May 1992	25
Indian Point	Entergy Nuclear Power Marketing, LLC	2,150	500	August 2001	16

Summary of Estimated Capacity and Other Fixed Payments

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

(Millions of Dollars)	2017	2018	2019	2020	2021	All Years Thereafter
Con Edison	$178	$125	$120	$76	$54	$710
CECONY	178	125	119	75	54	710

Summary of Capacity, Energy and Other Fixed Payments

The company’s payments under the agreements for capacity, energy and other fixed payments in 2016, 2015 and 2014 were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2016	2015	2014
Linden Cogeneration	$304	$323	$381
Indian Point	203	226	247
Astoria Energy (a)	50	178	230
Astoria Generating Company	16	—	—
Brooklyn Navy Yard	119	113	133
Indeck Corinth (b)	—	25	80
Selkirk (c)	—	—	144
Independence (c)	—	—	97
Total	$692	$865	$1,312

(a) Contract term ended in 2016.

(b) Contract term ended in 2015.

(c) Contract term ended in 2014

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Leases (Tables)

12 Months Ended

Dec. 31, 2016

Leases [Abstract]

Schedule of Capital Leases

The following assets under capital leases are included in the Companies’ consolidated balance sheets at December 31, 2016 and 2015:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
UTILITY PLANT
Common	$3	$3	$2	$2

Future Minimum Lease Commitments

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

(Millions of Dollars)	Con Edison	CECONY
2017	$1	$1
2018	1	1
2019	—	—
2020	—	—
2021	—	—
All years thereafter	—	—
Total	2	2
Less: amount representing interest	—	—
Present value of net minimum lease payment	$2	$2

Future Minimum Rental Payments for Operating Leases

The future minimum lease commitments under the Companies’ operating lease agreements that are not cancellable by the Companies are as follows:

(Millions of Dollars)	Con Edison	CECONY
2017	$61	$53
2018	62	54
2019	61	54
2020	61	54
2021	58	53
All years thereafter	788	696
Total	$1,091	$964

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Income Tax (Tables)

12 Months Ended

Dec. 31, 2016

Income Tax Disclosure [Abstract]

Schedule of Components of Income Tax

The components of income tax are as follows:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
State
Current	$(42)	$38	$59	$(1)	$48	$66
Deferred	188	93	61	114	82	65
Federal
Current	(43)	(86)	(9)	59	77	158
Deferred	604	569	463	435	372	271
Amortization of investment tax credits	(9)	(9)	(6)	(4)	(5)	(5)
Total income tax expense	$698	$605	$568	$603	$574	$555

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)	2016	2015	2016	2015
Deferred tax liabilities:
Property basis differences	$9,446	$8,614	$8,620	$7,922
Regulatory assets:
Unrecognized pension and other postretirement costs	1,162	1,562	1,104	1,490
Future income tax	986	947	940	899
Environmental remediation costs	333	365	287	322
Deferred storm costs	23	75	1	45
Other regulatory assets	371	367	321	308
Equity investments	363	295	—	—
Total deferred tax liabilities	$12,684	$12,225	$11,273	$10,986
Deferred tax assets:
Accrued pension and other postretirement costs	$581	$982	$467	$857
Regulatory liabilities	822	836	728	752
Superfund and other environmental costs	304	308	265	268
Asset retirement obligations	99	97	92	94
Loss carryforwards	59	29	—	—
Tax credits carryforward	498	258	—	1
Valuation allowance	(16)	(15)	—	—
Other	303	362	312	292
Total deferred tax assets	2,650	2,857	1,864	2,264
Net deferred tax liabilities	$10,034	$9,368	$9,409	$8,722
Unamortized investment tax credits	171	169	41	33
Net deferred tax liabilities and unamortized investment tax credits	$10,205	$9,537	$9,450	$8,755

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)	2016		2015		2014		2016		2015		2014
STATUTORY TAX RATE
Federal	35	%	35	%	35	%	35	%	35	%	35	%
Changes in computed taxes resulting from:
State income tax	4		5		5		4		5		5
Cost of removal	(1	)	(5	)	(5	)	(1	)	(5	)	(5	)
Renewable energy credits	(1	)	(1	)	—		—		—		—
Research and development credits	(1	)	—		—		(1	)	—		—
Other	—		—		(1	)	(1	)	—		(1	)
Effective tax rate	36	%	34	%	34	%	36	%	35	%	34	%

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)	2016	2015	2014	2016	2015		2014
Balance at January 1,	$34	$34	$9	$2		$2		$—
Additions based on tax positions related to the current year	2	—	—	2	—		—
Additions based on tax positions of prior years	19	1	27	19	—		2
Reductions for tax positions of prior years	(13)	—	(2)	(2)	—		—
Reductions from expiration of statute of limitations	—	(1)	—	—	—		—
Settlements	—	—	—	—	—		—
Balance at December 31,	$42	$34	$34	$21	$2		$2

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Stock-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2016

Disclosure of Compensation Related Costs, Share-based Payments [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, 2016, 2015 and 2014:

	Con Edison			CECONY
(Millions of Dollars)	2016	2015	2014	2016	2015	2014
Performance-based restricted stock	$42	$27	$22	$36	$23	$19
Time-based restricted stock	2	1	2	2	1	2
Non-employee director deferred stock compensation	2	2	2	2	2	2
Stock purchase plan	4	4	3	4	3	3
Total	$50	$34	$29	$44	$29	$26
Income tax benefit	$20	$14	$12	$18	$12	$10

Summary of Changes in Status of Stock Options

A summary of changes in the status of stock options as of December 31, 2016 is as follows:

	Con Edison		CECONY
	Shares	Weighted Average Exercise Price	Shares	Weighted Average Exercise Price
Outstanding at December 31, 2015	79,125	$43.50	65,775	$43.50
Exercised	79,125	43.50	65,775	43.50
Forfeited	—	—	—	—
Outstanding at December 31, 2016	—	$—	—	$—

Summary of Stock Options

The following table summarizes information about stock options for the years ended December 31, 2016 and 2015:

	Con Edison			CECONY
(Millions of Dollars)	2016		2015	2016		2015
Aggregate intrinsic value (a)
Options outstanding		$—	$2		$—	$1
Options exercised	2		3	2		3
Cash received by Con Edison for payment of exercise price	3		6	3		5

(a) Aggregate intrinsic value represents the changes in the fair value of all outstanding options from their grant dates to December 31 of the years presented above.

Assumptions Used to Calculate Fair Value of Awards

The assumptions used to calculate the fair value of the awards were as follows:

	2016	2015	2014
Risk-free interest rate (a)	0.85% - 1.20%	0.64% - 3.28%	0.23% - 3.07%
Expected term (b)	3 years	3 years	3 years
Expected share price volatility (c)	17.72% - 18.22%	15.82%	13.14%

(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, 2016 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, 2015	1,078,339	$45.26	$58.08	853,257	$45.37	$58.12
Granted	386,400	83.16	72.10	295,300	82.73	72.34
Vested	(351,230)	55.16	57.96	(285,162)	55.21	58.07
Forfeited	(26,372)	48.48	61.03	(15,053)	53.61	63.05
Non-vested at December 31, 2016	1,087,137	$55.45	$63.03	848,342	$54.92	$63.00

(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, 2016 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, 2015	64,980	$58.56	61,630	$58.55
Granted	23,000	76.62	21,800	76.62
Vested	(20,900)	61.03	(19,800)	61.03
Forfeited	(1,100)	60.13	(1,050)	60.43
Non-vested at December 31, 2016	65,980	$64.04	62,580	$64.03

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Financial Information by Business Segment (Tables)

12 Months Ended

Dec. 31, 2016

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, 2016 (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	$8,106	$17		$865	$1,847	$2		$459	$495	$30,708	$1,819
Gas	1,508	6		159	357	(1)		105	92	7,553	811
Steam	551	88		82	58	(1)		39	30	2,595	126
Consolidation adjustments	—	(111)		—	—	—		—	—	—	—
Total CECONY	$10,165		$—	$1,106	$2,262		$—	$603	$617	$40,856	$2,756
O&R
Electric	$637		$—	$49	$95	$1		$24	$30	$1,949	$114
Gas	184	—		18	35	—		12	10	809	52
Other	—	—		—	—	—		—	—	—	—
Total O&R	$821		$—	$67	$130	$1		$36	$40	$2,758	$166
Clean Energy Businesses	$1,091	$7		$42	$183	$21		$34	$53	$2,551	$1,235
Con Edison Transmission	—	—		—	(3)	43		6	—	1,150	1,078
Other (b)	(2)	(7)		1	3	(1)		17	4	940	—
Total Con Edison	$12,075		$—	$1,216	$2,575	$64		$696	$714	$48,255	$5,235

As of and for the Year Ended December 31, 2015 (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 (c)	Capital expenditures
CECONY
Electric	$8,172	$18		$820	$1,798	$(2)	$447	$447	$30,603	$1,658
Gas	1,527	6		142	356	(2)	96	100	6,974	671
Steam	629	86		78	93	(1)	41	41	2,653	106
Consolidation adjustments	—	(110)		—	—	—	—	—	—	—
Total CECONY	$10,328		$—	$1,040	$2,247	$(5)	$584	$588	$40,230	$2,435
O&R
Electric	$663		$—	$50	$103	$(2)	$23	$31	$2,140	$114
Gas	182	—		18	18	(2)	12	2	579	46
Other	—	—		—	—	—	—	—	—	—
Total O&R	$845		$—	$68	$121	$(4)	$35	$33	$2,719	$160
Clean Energy Businesses	$1,383	$(2)		$22	$58	$35	$11	$22	$1,680	$823
Con Edison Transmission	—	—		—	—	—	—	—	3	—
Other (b)	(2)	2		—	1	(2)	23	1	1,010	—
Total Con Edison	$12,554		$—	$1,130	$2,427	$24	$653	$644	$45,642	$3,418

As of and for the Year Ended December 31, 2014 (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 (c)	Capital expenditures
CECONY
Electric	$8,437	$16		$781	$1,712	$8	$412	$425	$30,295	$1,500
Gas	1,721	6		132	314	2	89	88	6,478	549
Steam	628	84		78	113	1	36	49	2,670	83
Consolidation adjustments	—	(106)		—	—	—	—	—	—	—
Total CECONY	$10,786		$—	$991	$2,139	$11	$537	$562	$39,443	$2,132
O&R
Electric	$680		$—	$46	$103	$3	$24	$29	$2,023	$105
Gas	212	—		15	25	—	10	6	786	37
Other	—	—		—	—	—	1	—	1	—
Total O&R	$892		$—	$61	$128	$3	$35	$35	$2,810	$142
Clean Energy Businesses	$1,244	$(10)		$19	$(60)	$28	$(8)	$(8)	$1,013	$447
Con Edison Transmission	—	—		—	—	—	—	—	1	—
Other (b)	(3)	10		—	2	—	27	—	804	—
Total Con Edison	$12,919		$—	$1,071	$2,209	$42	$591	$589	$44,071	$2,721

(a) For Con Edison, the income tax expense on non-operating income was $16 million, $40 million and $21 million in 2016, 2015 and 2014, respectively. For CECONY, the income tax expense on non-operating income was $14 million, $14 million and $7 million in 2016, 2015 and 2014, respectively.

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

(c) Reflects $237 million in 2014, related to the adoption of ASU No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs” and ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes.” See Notes C and L.

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Derivative Instruments and Hedging Activities (Tables)

12 Months Ended

Dec. 31, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Offsetting of Liabilities

The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at December 31, 2016 and 2015 were:

(Millions of Dollars)	2016				2015
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	$81	$(64)	$17	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	49	(43)	6		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$130	$(107)	$23		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(138)	$61	$(77)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(91)	52	(39)	(d)	(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(229)	$113	$(116)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(99)	$6	$(93)	(b)(d)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(45)	$7	(b)	$40	$(32)	$8	(b)
Noncurrent	41	(35)	6		48	(47)	1
Total fair value of derivative assets	$93	$(80)	$13		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(111)	$45	$(66)		$(121)	$71	$(50)
Noncurrent	(77)	44	(33)		(92)	56	(36)
Total fair value of derivative liabilities	$(188)	$89	$(99)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(95)	$9	$(86)	(b)	$(125)	$48	$(77)	(b)

(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, 2016 and 2015, margin deposits for Con Edison ($7 million and $26 million, respectively) and CECONY ($7 million and $26 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) Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet.

(d) Does not include ($1) million for interest rate swap (see below).

Offsetting of Assets

The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at December 31, 2016 and 2015 were:

(Millions of Dollars)	2016				2015
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	$81	$(64)	$17	(b)	$59	$(41)	$18	(b)
Current - assets held for sale (c)	—	—	—		51	(50)	1
Noncurrent	49	(43)	6		57	(54)	3
Noncurrent - assets held for sale (c)	—	—	—		15	(15)	—
Total fair value of derivative assets	$130	$(107)	$23		$182	$(160)	$22
Fair value of derivative liabilities
Current	$(138)	$61	$(77)		$(144)	$78	$(66)
Current - liabilities held for sale (c)	—	—	—		(115)	50	(65)
Noncurrent	(91)	52	(39)	(d)	(102)	63	(39)
Noncurrent - liabilities held for sale (c)	—	—	—		(28)	15	(13)
Total fair value of derivative liabilities	$(229)	$113	$(116)		$(389)	$206	$(183)
Net fair value derivative assets/(liabilities)	$(99)	$6	$(93)	(b)(d)	$(207)	$46	$(161)	(b)
CECONY
Fair value of derivative assets
Current	$52	$(45)	$7	(b)	$40	$(32)	$8	(b)
Noncurrent	41	(35)	6		48	(47)	1
Total fair value of derivative assets	$93	$(80)	$13		$88	$(79)	$9
Fair value of derivative liabilities
Current	$(111)	$45	$(66)		$(121)	$71	$(50)
Noncurrent	(77)	44	(33)		(92)	56	(36)
Total fair value of derivative liabilities	$(188)	$89	$(99)		$(213)	$127	$(86)
Net fair value derivative assets/(liabilities)	$(95)	$9	$(86)	(b)	$(125)	$48	$(77)	(b)

(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, 2016 and 2015, margin deposits for Con Edison ($7 million and $26 million, respectively) and CECONY ($7 million and $26 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) Amounts represent derivative assets and liabilities included in assets and liabilities held for sale on the consolidated balance sheet.

(d) Does not include ($1) million for interest rate swap (see below).

Realized and Unrealized Gains or Losses on Commodity Derivatives

The following table presents the realized and unrealized gains or losses on commodity derivatives that have been deferred or recognized in earnings for the years ended December 31, 2016 and 2015:

		Con Edison				CECONY
(Millions of Dollars)	Balance Sheet Location	2016		2015		2016			2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$23		$1		$18			$2
Noncurrent	Deferred derivative gains	1		1		2			—
Total deferred gains/(losses)		$24		$2		$20			$2
Current	Deferred derivative losses	$22		$(16)		$18			$(11)
Current	Recoverable energy costs	(212)		(136)		(194)			(127)
Noncurrent	Deferred derivative losses	2		(25)		4			(23)
Total deferred gains/(losses)		$(188)		$(177)		$(172)			$(161)
Net deferred gains/(losses)		$(164)		$(175)		$(152)			$(159)
	Income Statement Location
Pre-tax gain/(loss) recognized in income
	Purchased power expense	$(101)	(a)	$(109)	(b)		$—			$—
	Gas purchased for resale	(112)		(106)		—			—
	Non-utility revenue	9	(a)	30	(b)	—			—
	Other operations and maintenance expense	1	(c)	(1)	(d)	1		(c)	(1)		(d)
Total pre-tax gain/(loss) recognized in income		$(203)		$(186)		$1			$(1)

(a) For the year ended December 31, 2016, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($5 million loss) and purchased power expense ($11 million gain).

(b) For the year ended December 31, 2015, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($1 million gain) and purchased power expense ($1 million loss).

(c) For the year ended December 31, 2016, Con Edison and CECONY recorded an unrealized gain in other operations and maintenance expense ($1 million).

(d) For the year ended December 31, 2015, Con Edison and CECONY recorded an unrealized loss in other operations and maintenance expense ($1 million).

Hedged Volume of Derivative Transactions

The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at December 31, 2016:

	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	21,235,830	13,616	77,248,786	3,696,000
CECONY	19,258,400	7,500	71,060,000	3,696,000

(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, 2016:

(Millions of Dollars)	Con Edison (a)	CECONY (a)
Aggregate fair value – net liabilities	$113	$103
Collateral posted	43	42
Additional collateral (b) (downgrade one level from current ratings)	11	10
Additional collateral (b)(c) (downgrade to below investment grade from current ratings)	75	65

(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 $43 million at December 31, 2016. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

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

(c) Derivative instruments that are net assets have been excluded from the table. At December 31, 2016, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $15 million.

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Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2016

Fair Value Disclosures [Abstract]

Assets and Liabilities Measured at Fair Value on Recurring Basis

Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2016 and 2015 are summarized below.

	2016						2015
(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)	$14	$33	$7		$(24)	$30	$2	$25	$13		$7	$47
Commodity held for sale (f)	—	—	—		—	—	—	63	1		(63)	1
Other (a)(b)(d)	222	111	—		—	333	185	112	—		—	297
Total assets	$236	$144	$7		$(24)	$363	$187	$200	$14		$(56)	$345
Derivative liabilities:
Commodity (a)(b)(c)	$4	$144	$6		$(38)	$116	$16	$153	$1		$(65)	$105
Interest Rate Swap (a)(b)(c)(g)	—	1	—		—	1	—	—	—		—	—
Commodity held for sale (f)	—	—	—		—	—	1	133	7		(63)	78
Total liabilities	$4	$145	$6		$(38)	$117	$17	$286	$8		$(128)	$183
CECONY
Derivative assets:
Commodity (a)(b)(c)	$10	$19	$1		$(10)	$20	$1	$9	$8		$17	$35
Other (a)(b)(d)	200	106	—		—	306	171	105	—		—	276
Total assets	$210	$125	$1		$(10)	$326	$172	$114	$8		$17	$311
Derivative liabilities:
Commodity (a)(b)(c)	$1	$124		$—	$(26)	$99	$14	$129		$—	$(57)	$86

(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. There were no transfers between levels 1, 2 and 3 for the years ended December 31, 2016 and 2015.

(b) Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, interest rate swap, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.

(c) The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2016 and 2015, 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) Amounts represent derivative assets and liabilities included in Assets and Liabilities held for sale on the consolidated balance sheet (see Note U).

(g) See Note O.

Schedule of Commodity Derivatives

The risk management group reports to the Companies’ Vice President and Treasurer.

	Fair Value of Level 3 at December 31, 2016
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison — Commodity
Electricity	$(1)	Discounted Cash Flow	Forward energy prices (a)	$37.75-$55.00 per MWh
		Discounted Cash Flow	Forward capacity prices (a)	$2.42-$10.25 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights	2	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
			Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(75.2)%-58.9%
			Inter-zonal forward price curves adjusted for historical zonal losses (b)	$1.11-$2.90 per MWh
Total Con Edison — Commodity	$1
CECONY — Commodity
Transmission Congestion Contracts	$1	Discounted Cash Flow	Discount to adjust auction prices for inter-zonal forward price curves (b)	50.0%
			Discount/(premium) to adjust auction prices for historical monthly realized settlements (b)	(75.2)%-58.9%

(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, 2016 and 2015 and classified as Level 3 in the fair value hierarchy:

	Con Edison		CECONY
(Millions of Dollars)	2016	2015	2016	2015
Beginning balance as of January 1,	$6	$20	$8	$13
Included in earnings	(7)	(20)	(1)	(6)
Included in regulatory assets and liabilities	(6)	1	(6)	—
Purchases	4	11	2	5
Sales (a)	4	—	—	—
Settlements	—	(6)	(2)	(4)
Ending balance as of December 31,	$1	$6	$1	$8

(a)Amounts represent derivative instruments novated as part of the assets of Con Edison Solutions’ retail electric supply business which were sold to a subsidiary of Exelon Corporation (see Note U).

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Variable Interest Entities (Tables)

12 Months Ended

Dec. 31, 2016

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Business Acquisitions, by Acquisition

(Millions of Dollars)	2016	2015
Restricted cash	$8	$9
Receivable from parent company	35	32
Non-utility property, less accumulated depreciation of $9 and $5, respectively	104	107
Other assets	8	11
Total assets (a)	$155	$159
Long-term debt due within one year	$3	$2
Other liabilities	38	37
Long-term debt	60	62
Total liabilities (b)	$101	$101

(a) The assets of Texas Solar 4 represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE.

(b) The liabilities of Texas Solar 4 represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary.

Summary of VIEs

The following table summarizes the VIEs in which Con Edison Development has entered into as of December 31, 2016:

Project Name (a)	Generating Capacity (b) (MW AC)	Power Purchase Agreement Term in Years	Year of Initial Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (c)
Copper Mountain Solar 3	128	20	2014	Nevada	$179
Mesquite Solar 1	83	20	2013	Arizona	108
Copper Mountain Solar 2	75	25	2013	Nevada	84
California Solar	55	25	2012	California	69
Broken Bow II	38	25	2014	Nebraska	48
Texas Solar 4	32	25	2014	Texas	47

(a) With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. With the exception of Texas Solar 4, Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development.

(b) Represents Con Edison Development’s ownership interest in the project.

(c) For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet. For consolidated investments, such as Texas Solar 4, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest ($7 million for Texas Solar 4). Con Edison did not provide any financial or other support during the year that was not previously contractually required.

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Related Party Transactions (Tables)

12 Months Ended

Dec. 31, 2016

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, 2016, 2015 and 2014 were as follows:

	CECONY
(Millions of Dollars)	2016	2015	2014
Cost of services provided	$108	$99	$90
Cost of services received	64	60	57

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General (Details)	12 Months Ended
	Dec. 31, 2016 subsidiary registrant
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 - Plant and Depreciation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Public Utility, Property, Plant and Equipment [Line Items]
Annual aggregate depreciation allowance	$ 1,176
Non Utility Plant | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	3 years
Non Utility Plant | Maximum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	30 years
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
Annual aggregate depreciation allowance	$ 1,106
AFUDC rates (percent)	4.70%	4.40%	1.60%
Average depreciation rates (percent)	3.10%	3.10%	3.10%
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)	85 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)	3.50%	0.40%	2.60%
Average depreciation rates (percent)	2.90%	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 | Gas | Minimum
Public Utility, Property, Plant and Equipment [Line Items]
Estimated useful lives (years)	5 years
O&R | Gas | 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 - Capitalized Cost of Utility Plant (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 2,719	$ 2,622
Held for future use	74	77
Construction work in progress	1,175	1,003
NET UTILITY PLANT	33,045	31,133
Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	479	459
Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	3,184	3,045
Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	18,150	17,244
Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	6,285	5,698
Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,882	1,849
General
Public Utility, Property, Plant and Equipment [Line Items]
General	1,816	1,758
CECONY
Public Utility, Property, Plant and Equipment [Line Items]
General	2,490	2,411
Held for future use	65	65
Construction work in progress	1,104	922
NET UTILITY PLANT	31,115	29,310
CECONY | Electric Generation
Public Utility, Property, Plant and Equipment [Line Items]
Generation	479	459
CECONY | Electric Transmission
Public Utility, Property, Plant and Equipment [Line Items]
Transmission	2,963	2,833
CECONY | Electric Distribution
Public Utility, Property, Plant and Equipment [Line Items]
Distribution	17,234	16,394
CECONY | Gas
Public Utility, Property, Plant and Equipment [Line Items]
Gas	5,749	5,196
CECONY | Steam
Public Utility, Property, Plant and Equipment [Line Items]
Steam	1,882	1,849
CECONY | General
Public Utility, Property, Plant and Equipment [Line Items]
General	$ 1,639	$ 1,592

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Summary of Significant Accounting Policies - Goodwill (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($)
Accounting Policies [Abstract]
Goodwill, impairment charge	$ 15

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Summary of Significant Accounting Policies - Long-Lived and Intangible Assets (Details) - USD ($)		12 Months Ended
	Sep. 30, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment charges		$ 0		$ 0
Discontinued Operations, Held-for-sale | Pike
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment charge on assets held for sale	$ 5,000,000		$ 5,000,000

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Summary of Significant Accounting Policies - Revenues (Details)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Revenue deferral period (months)	12 months

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Summary of Significant Accounting Policies - Schedule of Total Excise Taxes Recorded in Operating Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Excise Taxes [Line Items]
Excise taxes	$ 336	$ 354	$ 365
CECONY
Schedule of Excise Taxes [Line Items]
Excise taxes	$ 316	$ 331	$ 343

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Summary of Significant Accounting Policies - Recoverable Energy Costs (Details)	12 Months Ended
	Dec. 31, 2016
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 - Investments (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 488	$ 574
Supplemental retirement income plan assets	273	243
Deferred income plan assets	60	55
Other	9	9
Total investments	1,921	884
Stagecoach Gas Services, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	992
Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	48
CET | Stagecoach Gas Services, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	992	0
CET | New York Transco, LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	51	3
CET | Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	48	0
CECONY
Schedule of Equity Method Investments [Line Items]
Equity method investments	0	0
Supplemental retirement income plan assets	246	221
Deferred income plan assets	60	55
Other	9	10
Total investments	315	286
CECONY | CET | Stagecoach Gas Services, LLC
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
CECONY | CET | Mountain Valley Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity method investments	$ 0	$ 0

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Summary of Significant Accounting Policies - Pension and Other Postretirement Benefits (Details)	12 Months Ended
	Dec. 31, 2016
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 - Research and Development Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Research and Development Expenses [Line Items]
Research and development costs	$ 24	$ 23	$ 22
CECONY
Research and Development Expenses [Line Items]
Research and development costs	$ 22	$ 22	$ 20

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Summary of Significant Accounting Policies - Earnings Per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
Net income	$ 1,245	$ 1,193	$ 1,092
Weighted average common shares outstanding – basic	300.4	293.0	292.9
Add: Incremental shares attributable to effect of potentially dilutive securities	1.5	1.4	1.1
Adjusted weighted average common shares outstanding – diluted	301.9	294.4	294.0
Net income per common share — basic (dollars per share)	$ 4.15	$ 4.07	$ 3.73
Net income per common share — diluted (dollars per share)	$ 4.12	$ 4.05	$ 3.71

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Summary of Significant Accounting Policies - Changes in Accumulated Other Comprehensive Income by Component (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	$ 13,061	$ 12,585	$ 12,245
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	7	11	(20)
BALANCE AS OF END OF PERIOD	14,306	13,061	12,585
OCI before reclassifications, tax	(1)	(3)
Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(34)	(45)	(25)
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	7	11	(20)
BALANCE AS OF END OF PERIOD	(27)	(34)	(45)
Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	2	5
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	5	6
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	7	11
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	(3)	(4)
CECONY
AOCI Attributable to Parent, Net of Tax [Roll Forward]
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	2	2	(5)
OCI before reclassifications, tax	(1)
CECONY | Accumulated OCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
BALANCE AS OF BEGINNING OF PERIOD	(9)	(11)
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	2	2	(5)
BALANCE AS OF END OF PERIOD	(7)	(9)	$ (11)
CECONY | Pension Plan Liabilities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
OCI before reclassifications, net of tax	1	1
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax	1	1
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES	2	2
Amounts reclassified from accumulated OCI related to pension plan liabilities, tax	$ (1)	$ (1)

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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, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2019	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Cost reconciliations, deferred net regulatory liabilities	$ 986,000,000	$ 986,000,000	$ 947,000,000			$ 986,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Cost reconciliations, deferred net regulatory liabilities	940,000,000	940,000,000	899,000,000			940,000,000
CECONY | Electric
Public Utilities, General Disclosures [Line Items]
Deferred revenues	101,000,000	101,000,000	98,000,000	$ 146,000,000		101,000,000
Negative revenue adjustments		0	0	5,000,000
Cost reconciliations, deferred net regulatory liabilities	68,000,000	68,000,000	26,000,000	57,000,000		$ 68,000,000
Deferred regulatory asset		9,000,000	17,000,000	6,000,000
Earnings sharing, threshold limit		6,500,000	44,400,000	$ 0
Common equity ratio (percent)						48.00%
Base rate change deferral regulatory liability impact	0	$ 0	$ 30,000,000			$ 0
Increase in gas base rate due to expiration of temporary credit under the prior rate plan	$ 48,000,000
Deferrals for property taxes limitation from rates (percent)		90.00%
Recovery deferral (percentage)	80.00%	80.00%				80.00%
Maximum deferral (percentage)	30.00%	30.00%				30.00%
CECONY | Electric | Deferred storm costs
Public Utilities, General Disclosures [Line Items]
Amortization of regulatory asset		$ 107,000,000
Decrease in recoverable property damage costs		4,000,000
CECONY | Electric | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Amortization to income of net regulatory (assets) and liabilities		123,000,000
Authorized return on common equity (percent)					9.00%
Earnings sharing (percentage)					9.50%
Common equity ratio (percent)					48.00%
Recovery or refund of energy costs, deferral period					10 years
CECONY | Electric | Scenario, Forecast | NYSPSC
Public Utilities, General Disclosures [Line Items]
Base rate changes					$ 199,000,000
CECONY | Electric | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes	$ (76,200,000)	$ (76,200,000)				$ (76,200,000)
Amortization to income of net regulatory (assets) and liabilities						(37,000,000)
Retention of annual transmission congestion revenues						90,000,000
Average rate base						$ 17,323,000,000
Weighted average cost of capital (after-tax) (percent)						7.05%
Authorized return on common equity (percent)						9.20%
Earnings sharing (percentage)	9.80%	9.80%				9.80%
Cost of long-term debt (percent)	5.17%	5.17%				5.17%
Deferral, annual maximum (not more than) (percent)		0.05%
CECONY | Electric | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						$ 400,000,000
CECONY | Electric | Year 1 | Transmission and distribution
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						16,869,000,000
CECONY | Electric | Year 1 | Storm hardening
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						89,000,000
CECONY | Electric | Year 1 | Other
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						2,034,000,000
CECONY | Electric | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					195,000,000
Amortization to income of net regulatory (assets) and liabilities					84,000,000
Retention of annual transmission congestion revenues					75,000,000
Potential earnings adjustment mechanism incentives					28,000,000
Potential penalties (annually)					376,000,000
Average rate base					$ 18,902,000,000
Weighted average cost of capital (after-tax) (percent)					6.82%
Cost of long-term debt (percent)					4.93%
Recovery of energy efficiency and savings program costs					$ 20,500,000
CECONY | Electric | Year 1 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset					21,689,000,000
CECONY | Electric | Year 1 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset					126,000,000
CECONY | Electric | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes	$ 124,000,000	$ 124,000,000				124,000,000
Amortization to income of net regulatory (assets) and liabilities						(37,000,000)
Retention of annual transmission congestion revenues						90,000,000
Average rate base						$ 18,113,000,000
Weighted average cost of capital (after-tax) (percent)						7.08%
Authorized return on common equity (percent)						9.20%
Earnings sharing (percentage)	9.80%	9.80%				9.80%
Cost of long-term debt (percent)	5.23%	5.23%				5.23%
Deferral, annual maximum (not more than) (percent)		0.075%
CECONY | Electric | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						$ 400,000,000
CECONY | Electric | Year 2 | Transmission and distribution
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						17,401,000,000
CECONY | Electric | Year 2 | Storm hardening
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						177,000,000
CECONY | Electric | Year 2 | Other
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						2,102,000,000
CECONY | Electric | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					155,000,000
Amortization to income of net regulatory (assets) and liabilities					83,000,000
Retention of annual transmission congestion revenues					75,000,000
Potential earnings adjustment mechanism incentives					47,000,000
Potential penalties (annually)					383,000,000
Average rate base					$ 19,530,000,000
Weighted average cost of capital (after-tax) (percent)					6.80%
Cost of long-term debt (percent)					4.88%
Recovery of energy efficiency and savings program costs					$ 49,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset					22,338,000,000
CECONY | Electric | Year 2 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset					257,000,000
CECONY | Electric | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes	$ 0	$ 0				0
Amortization to income of net regulatory (assets) and liabilities						123,000,000
Retention of annual transmission congestion revenues						90,000,000
Average rate base						$ 18,282,000,000
Weighted average cost of capital (after-tax) (percent)						6.91%
Authorized return on common equity (percent)						9.00%
Earnings sharing (percentage)	9.60%	9.60%				9.60%
Cost of long-term debt (percent)	5.09%	5.09%				5.09%
Deferral, annual maximum (not more than) (percent)		0.10%
CECONY | Electric | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						$ 400,000,000
CECONY | Electric | Year 3 | Transmission and distribution
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						17,929,000,000
CECONY | Electric | Year 3 | Storm hardening
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						268,000,000
CECONY | Electric | Year 3 | Other
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset						$ 2,069,000,000
CECONY | Electric | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					155,000,000
Amortization to income of net regulatory (assets) and liabilities					69,000,000
Retention of annual transmission congestion revenues					75,000,000
Potential earnings adjustment mechanism incentives					64,000,000
Potential penalties (annually)					395,000,000
Average rate base					$ 20,277,000,000
Weighted average cost of capital (after-tax) (percent)					6.73%
Cost of long-term debt (percent)					4.74%
Recovery of energy efficiency and savings program costs					$ 107,500,000
CECONY | Electric | Year 3 | Scenario, Forecast | Electric average excluding AMI
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset					23,002,000,000
CECONY | Electric | Year 3 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Deferred regulatory asset					$ 415,000,000

XML

Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Gas) (Details) - USD ($)	9 Months Ended	12 Months Ended			36 Months Ended
	Sep. 30, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2019	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Cost reconciliations, deferred net regulatory liabilities		$ 986,000,000	$ 947,000,000			$ 986,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Cost reconciliations, deferred net regulatory liabilities		940,000,000	899,000,000			940,000,000
CECONY | Gas
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained		65,000,000	66,000,000	$ 70,000,000		$ 65,000,000
Percentage of revenue reserve						15.00%
Deferred revenues		71,000,000	54,000,000	28,000,000		$ 71,000,000
Potential penalties (annually)		56,000,000	44,000,000	33,000,000
Negative revenue adjustments		0	0	0
Cost reconciliations, deferred net regulatory liabilities		$ 32,000,000	11,000,000	38,000,000		$ 32,000,000
Net utility plant reconciliations			1,000,000
Earnings sharing (percentage)		9.90%				9.90%
Earnings sharing, threshold limit		$ 0	$ 0	$ 0
Common equity ratio (percent)						48.00%
Base rate change deferral regulatory liability impact		$ 32,000,000				$ 32,000,000
Increase in gas base rate due to expiration of temporary credit under the prior rate plan	$ 41,000,000
Difference in property taxes (percent)		90.00%
Deferral, annual maximum (not more than) (percent)		0.10%
CECONY | Gas | Maximum
Public Utilities, General Disclosures [Line Items]
Amount of revenues retained		$ 65,000,000				65,000,000
CECONY | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Percentage of revenue reserve					15.00%
Earnings sharing (percentage)					9.50%
Common equity ratio (percent)					48.00%
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						(54,600,000)
Amortization to income of net regulatory (assets) and liabilities						4,000,000
Average rate base						$ 3,521,000,000
Weighted average cost of capital (after-tax) (percent)						7.10%
Authorized return on common equity (percent)						9.30%
Cost of long-term debt (percent)		5.17%				5.17%
CECONY | Gas | Year 1 | Gas delivery
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 3,899,000,000
CECONY | Gas | Year 1 | Storm hardening
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						3,000,000
CECONY | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					(5,000,000)
Amortization to income of net regulatory (assets) and liabilities					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)					9.00%
Cost of long-term debt (percent)					4.93%
CECONY | Gas | Year 1 | Scenario, Forecast | Gas excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 5,844,000,000
CECONY | Gas | Year 1 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					27,000,000
CECONY | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes						38,600,000
Amortization to income of net regulatory (assets) and liabilities						4,000,000
Average rate base						$ 3,863,000,000
Weighted average cost of capital (after-tax) (percent)						7.13%
Cost of long-term debt (percent)		5.23%				5.23%
CECONY | Gas | Year 2 | Gas delivery
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 4,258,000,000
CECONY | Gas | Year 2 | Storm hardening
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						8,000,000
CECONY | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					92,000,000
Amortization to income of net regulatory (assets) and liabilities					37,000,000
Potential incentives if performance targets are met					8,000,000
Potential penalties (annually)					75,000,000
Average rate base					$ 5,395,000,000
Weighted average cost of capital (after-tax) (percent)					6.80%
Cost of long-term debt (percent)					4.88%
CECONY | Gas | Year 2 | Scenario, Forecast | Gas excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 6,512,000,000
CECONY | Gas | Year 2 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					57,000,000
CECONY | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes						56,800,000
Amortization to income of net regulatory (assets) and liabilities						4,000,000
Average rate base						$ 4,236,000,000
Weighted average cost of capital (after-tax) (percent)						7.21%
Cost of long-term debt (percent)		5.39%				5.39%
CECONY | Gas | Year 3 | Gas delivery
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 4,698,000,000
CECONY | Gas | Year 3 | Storm hardening
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations						$ 30,000,000
CECONY | Gas | Year 3 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes					90,000,000
Amortization to income of net regulatory (assets) and liabilities					36,000,000
Potential incentives if performance targets are met					8,000,000
Potential penalties (annually)					83,000,000
Average rate base					$ 6,005,000,000
Weighted average cost of capital (after-tax) (percent)					6.73%
Cost of long-term debt (percent)					4.74%
CECONY | Gas | Year 3 | Scenario, Forecast | Gas excluding AMI
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 7,177,000,000
CECONY | Gas | Year 3 | Scenario, Forecast | Advanced metering infrastructure (AMI)
Public Utilities, General Disclosures [Line Items]
Net utility plant reconciliations					$ 100,000,000

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Regulatory Matters - Summary of Utilities Rate Plans (CECONY-Steam) (Details) - USD ($)	12 Months Ended			36 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2016
Public Utilities, General Disclosures [Line Items]
Cost reconciliation, deferred net regulatory liabilities	$ 986,000,000	$ 947,000,000		$ 986,000,000
Cost reconciliations, deferred net regulatory assets	822,000,000	836,000,000		822,000,000
CECONY
Public Utilities, General Disclosures [Line Items]
Cost reconciliation, deferred net regulatory liabilities	940,000,000	899,000,000		940,000,000
Cost reconciliations, deferred net regulatory assets	728,000,000	752,000,000		728,000,000
CECONY | Steam
Public Utilities, General Disclosures [Line Items]
Negative revenue adjustments	0	0	$ 0
Cost reconciliation, deferred net regulatory liabilities	$ 8,000,000		42,000,000	$ 8,000,000
Cost reconciliations, deferred net regulatory assets		17,000,000
Deferred regulatory liability (reduction)			100,000
Authorized return on common equity (percent)				9.30%
Earnings sharing (percentage)	9.90%			9.90%
Earnings sharing, threshold limit	$ 7,800,000	$ 11,500,000	$ 0
Common equity ratio (percent)				48.00%
Other regulatory liabilities	$ 8,000,000			$ 8,000,000
Difference in property taxes (percent)	90.00%
Deferral, annual maximum (not more than) (percent)	0.10%
CECONY | Steam | Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes				(22,400,000)
Amortization to income of net regulatory (assets) and liabilities				37,000,000
Average rate base				$ 1,511,000,000
Weighted average cost of capital (after-tax) (percent)				7.10%
Cost of long-term debt (percent)	5.17%			5.17%
CECONY | Steam | Year 1 | Production
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability (reduction)				$ 1,752,000,000
CECONY | Steam | Year 1 | Distribution
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability (reduction)				6,000,000
CECONY | Steam | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				1,000,000
CECONY | Steam | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes				19,800,000
Amortization to income of net regulatory (assets) and liabilities				37,000,000
Average rate base				$ 1,547,000,000
Weighted average cost of capital (after-tax) (percent)				7.13%
Cost of long-term debt (percent)	5.23%			5.23%
CECONY | Steam | Year 2 | Production
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability (reduction)				$ 1,732,000,000
CECONY | Steam | Year 2 | Distribution
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability (reduction)				11,000,000
CECONY | Steam | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				1,000,000
CECONY | Steam | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes				20,300,000
Amortization to income of net regulatory (assets) and liabilities				37,000,000
Average rate base				$ 1,604,000,000
Weighted average cost of capital (after-tax) (percent)				7.21%
Cost of long-term debt (percent)	5.39%			5.39%
CECONY | Steam | Year 3 | Production
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability (reduction)				$ 1,720,000,000
CECONY | Steam | Year 3 | Distribution
Public Utilities, General Disclosures [Line Items]
Deferred regulatory liability (reduction)				25,000,000
CECONY | Steam | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)				1,000,000
CECONY | Steam | Year 4
Public Utilities, General Disclosures [Line Items]
Base rate changes				$ 0

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Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Electric) (Details) - O&R - Electric - USD ($)	12 Months Ended					24 Months Ended	36 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Oct. 31, 2017	Jun. 30, 2015
Public Utilities, General Disclosures [Line Items]
Deferred revenues	$ 6,300,000	$ 6,300,000	$ (3,400,000)	$ 3,200,000	$ 2,600,000
Negative revenue adjustments	0	1,250,000	0	0	0
Deferral of net increase (decrease) to regulatory assets	7,400,000	300,000	(200,000)	4,100,000	7,800,000
Deferred regulatory liability (reduction)	(1,900,000)	$ 2,200,000	(2,300,000)	$ (1,100,000)	$ 4,200,000
Earnings sharing, threshold limit	$ 6,100,000		$ 1,000,000
Common equity ratio (percent)							48.00%
Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)						9.00%
Earnings sharing (percentage)						9.60%
Common equity ratio (percent)						48.00%
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
Scenario, Forecast | Property Tax and Interest Rate Reconciliations
Public Utilities, General Disclosures [Line Items]
Regulatory assets not recoverable						4,000,000
Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes							$ 19,400,000
Amortization to income of net regulatory (assets) and liabilities							(32,200,000)
Deferred regulatory liability (reduction)							678,000,000
Average rate base							$ 671,000,000
Weighted average cost of capital (after-tax) (percent)							7.61%
Authorized return on common equity (percent)							9.40%
Cost of long-term debt (percent)							6.07%
Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							$ 3,000,000
Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						9,300,000
Amortization to income of net regulatory (assets) and liabilities						(8,500,000)
Deferred regulatory liability (reduction)						928,000,000
Average rate base						$ 763,000,000
Weighted average cost of capital (after-tax) (percent)						7.10%
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
Year 1 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						4,000,000
Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes							8,800,000
Amortization to income of net regulatory (assets) and liabilities							(32,200,000)
Deferred regulatory liability (reduction)							704,000,000
Average rate base							$ 708,000,000
Weighted average cost of capital (after-tax) (percent)							7.65%
Authorized return on common equity (percent)							9.50%
Cost of long-term debt (percent)							6.07%
Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							$ 3,000,000
Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						8,800,000
Amortization to income of net regulatory (assets) and liabilities						(9,400,000)
Deferred regulatory liability (reduction)						970,000,000
Average rate base						$ 805,000,000
Weighted average cost of capital (after-tax) (percent)						7.06%
Cost of long-term debt (percent)						5.35%
Deferred storm and property reserve deficiency, noncurrent						$ 11,850,000
Rate exclusion amount with balance below regulatory threshold						9,000,000
Year 2 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						$ 4,000,000
Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes							15,200,000
Amortization to income of net regulatory (assets) and liabilities							(32,200,000)
Deferred regulatory liability (reduction)							753,000,000
Average rate base							$ 759,000,000
Weighted average cost of capital (after-tax) (percent)							7.48%
Authorized return on common equity (percent)							9.60%
Cost of long-term debt (percent)							5.64%
Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							$ 3,000,000

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Regulatory Matters - Summary of Utilities Rate Plans (O&R New York-Gas) (Details) - USD ($)	12 Months Ended					36 Months Ended	62 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Oct. 31, 2018	Dec. 31, 2014
Public Utilities, General Disclosures [Line Items]
Cost reconciliations, deferred net regulatory assets	$ 822,000,000	$ 836,000,000
O&R | Gas
Public Utilities, General Disclosures [Line Items]
Deferred revenues	6,200,000	(800,000)	$ (100,000)	$ 700,000	$ 4,700,000		$ (100,000)
Negative revenue adjustments	0	0	0	0	0
Cost reconciliations, deferred net regulatory assets	6,600,000	4,500,000	8,300,000	8,300,000	700,000		$ 8,300,000
Net utility plant reconciliations		$ 0	0	0	700,000
Weighted average cost of capital (after-tax) (percent)							8.49%
Authorized return on common equity (percent)							10.40%
Earnings sharing, threshold limit	$ 4,000,000		$ 0	$ 0	$ 0
Cost of long-term debt (percent)			6.81%				6.81%
Common equity ratio (percent)							48.00%
O&R | Gas | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Authorized return on common equity (percent)						9.00%
Common equity ratio (percent)						48.00%
O&R | Gas | Scenario, Forecast | 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							$ 9,000,000
Amortization to income of net regulatory (assets) and liabilities							(2,000,000)
Average rate base							$ 280,000,000
Earnings sharing (percentage)			11.40%				11.40%
O&R | Gas | Year 1 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							$ 1,400,000.0
O&R | Gas | Year 1 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						16,400,000
Amortization to income of net regulatory (assets) and liabilities						(1,700,000)
Average rate base						$ 366,000,000
Weighted average cost of capital (after-tax) (percent)						7.10%
Earnings sharing (percentage)						9.60%
Cost of long-term debt (percent)						5.42%
Rate exclusion amount with balance below regulatory threshold						$ 500,000
O&R | Gas | Year 1 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						3,700,000.0
Net utility plant reconciliations						492,000,000
O&R | Gas | Year 2
Public Utilities, General Disclosures [Line Items]
Base rate changes							9,000,000
Amortization to income of net regulatory (assets) and liabilities							(2,000,000)
Average rate base							$ 296,000,000
Earnings sharing (percentage)			11.40%				11.40%
O&R | Gas | Year 2 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							$ 1,400,000.0
O&R | Gas | Year 2 | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Base rate changes						16,400,000
Amortization to income of net regulatory (assets) and liabilities						(2,100,000)
Average rate base						$ 391,000,000
Weighted average cost of capital (after-tax) (percent)						7.06%
Earnings sharing (percentage)						9.60%
Cost of long-term debt (percent)						5.35%
Rate exclusion amount with balance below regulatory threshold						$ 4,200,000
O&R | Gas | Year 2 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						4,700,000.0
Net utility plant reconciliations						518,000,000
O&R | Gas | Year 3
Public Utilities, General Disclosures [Line Items]
Base rate changes							4,600,000
Base rate change through surcharge							4,300,000
Amortization to income of net regulatory (assets) and liabilities							(2,000,000)
Average rate base							$ 309,000,000
Earnings sharing (percentage)			11.40%				11.40%
O&R | Gas | Year 3 | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)							$ 1,400,000.0
O&R | Gas | Year 3 | Scenario, Forecast
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) and liabilities						(2,500,000)
Average rate base						$ 417,000,000
Weighted average cost of capital (after-tax) (percent)						7.06%
Earnings sharing (percentage)						9.60%
Cost of long-term debt (percent)						5.35%
Rate exclusion amount with balance below regulatory threshold						$ 7,200,000
O&R | Gas | Year 3 | Scenario, Forecast | Maximum
Public Utilities, General Disclosures [Line Items]
Potential penalties (annually)						5,800,000.0
Net utility plant reconciliations						$ 546,000,000
O&R | Gas | Year 4
Public Utilities, General Disclosures [Line Items]
Base rate change through surcharge							0
O&R | Gas | Year 5
Public Utilities, General Disclosures [Line Items]
Base rate change through surcharge							$ 0

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Regulatory Matters - Summary of Utilities Rate Plans (Rockland Electric Company (RECO)) (Details) - Rockland Electric Company (RECO) - USD ($) $ in Millions	1 Months Ended	12 Months Ended	51 Months Ended
	Jan. 31, 2016	Jul. 31, 2015	Jul. 31, 2014
Public Utilities, General Disclosures [Line Items]
Average rate base		$ 172.2	$ 148.6
Weighted average cost of capital (after-tax) (percent)		7.83%	8.21%
Authorized return on common equity (percent)		9.75%	10.30%
Cost of long-term debt (percent)		5.89%	6.16%
Common equity ratio (percent)		50.00%	50.00%
Electric
Public Utilities, General Disclosures [Line Items]
RECO plan period (years)	3 years
RECO plan electric system storm hardening amount	$ 15.7
Year 1
Public Utilities, General Disclosures [Line Items]
Base rate changes		$ 13.0	$ 9.8
Amortization to income of net regulatory (assets) and liabilities		0.4	(3.9)
Deferred major storm costs		(25.6)	(4.9)
Year 2
Public Utilities, General Disclosures [Line Items]
Amortization to income of net regulatory (assets) and liabilities		0.4	(3.9)
Deferred major storm costs		(25.6)	(4.9)
Year 3
Public Utilities, General Disclosures [Line Items]
Amortization to income of net regulatory (assets) and liabilities		0.4	(3.9)
Deferred major storm costs		(25.6)	(4.9)
Year 4
Public Utilities, General Disclosures [Line Items]
Amortization to income of net regulatory (assets) and liabilities			(3.9)
Deferred major storm costs		$ (25.6)	(4.9)
Year 5
Public Utilities, General Disclosures [Line Items]
Deferred major storm costs			$ (4.9)

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Regulatory Matters - Additional Information (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Feb. 16, 2017	Jan. 31, 2017	Oct. 31, 2016	Dec. 31, 2016	Dec. 31, 2015
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities				$ 1,905.0	$ 1,977.0
FERC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested return on equity (percent)		10.70%
Requested equity capital structure (percent)		48.00%
Rockland Electric Company (RECO) | NJBPU | Subsequent Event | Rockland Electric Company (RECO) | Electric
Public Utilities, General Disclosures [Line Items]
Interim rate increase, amount	$ 1.7
Requested return on equity (percent)	9.60%
Requested equity capital structure (percent)	49.70%
Rockland Electric Company (RECO) | FERC
Public Utilities, General Disclosures [Line Items]
Requested rate increase, amount				11.8
Rockland Electric Company (RECO) | FERC | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested rate increase, amount		$ 19.7
CECONY
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities				1,712.0	$ 1,789.0
CECONY | June 2014 Plastic Fusion Proceeding
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities				$ 27.0
CECONY | Subsequent Event | June 2014 Plastic Fusion Proceeding
Public Utilities, General Disclosures [Line Items]
Loss from settlement	$ 126.0
CECONY | NYSPSC
Public Utilities, General Disclosures [Line Items]
Risk assessment and remediation plan, period			3 years

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Regulatory Matters - Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	$ 1,905	$ 1,977
Regulatory liabilities—current	128	115
Total Regulatory Liabilities	2,033	2,092
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	7,024	8,096
Regulatory assets – current	100	132
Total Regulatory Assets	7,124	8,228
Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	755	676
Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	193	76
Property tax reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	178	303
Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	145	109
Prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	95	99
Carrying charges on repair allowance and bonus depreciation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	68	49
New York State income tax rate change
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	61	75
Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	60	28
Variable-rate tax-exempt debt - cost rate reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	55	70
Base rate change deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	40	128
Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	39	80
Net utility plant reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	16	32
Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1	44
World Trade Center settlement proceeds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	21
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	199	187
Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	71	45
Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	29	64
Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	28	6
Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,874	3,876
Future income tax
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,439	2,350
Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	823	904
Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	295	253
Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	56	185
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	48	50
Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	43	50
Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	42	16
Regulatory assets – current	9	19
Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	38	45
O&R property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	37	46
Surcharge for New York State assessment
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	28	44
Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	25	26
Net electric deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	24	44
O&R transition bond charges
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	15	21
Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	13	11
Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	224	175
Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	91	113
CECONY
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1,712	1,789
Regulatory liabilities—current	90	84
Total Regulatory Liabilities	1,802	1,873
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	6,473	7,482
Regulatory assets – current	90	121
Total Regulatory Assets	6,563	7,603
CECONY | Allowance for cost of removal less salvage
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	641	570
CECONY | Pension and other postretirement benefit deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	162	46
CECONY | Property tax reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	178	303
CECONY | Net unbilled revenue deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	145	109
CECONY | Prudence proceeding
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	95	99
CECONY | Carrying charges on repair allowance and bonus depreciation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	67	48
CECONY | New York State income tax rate change
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	60	72
CECONY | Unrecognized other postretirement costs
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	60	28
CECONY | Variable-rate tax-exempt debt - cost rate reconciliation
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	48	60
CECONY | Base rate change deferrals
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	40	128
CECONY | Earnings sharing - electric, gas and steam
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	28	80
CECONY | Net utility plant reconciliations
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	15	31
CECONY | Property tax refunds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	1	44
CECONY | World Trade Center settlement proceeds
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	0	21
CECONY | Other
Regulatory Liabilities [Line Items]
Regulatory liabilities – noncurrent	172	150
CECONY | Revenue decoupling mechanism
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	61	45
CECONY | Refundable energy costs
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	5	33
CECONY | Deferred derivative gains
Regulatory Liabilities [Line Items]
Regulatory liabilities—current	24	6
CECONY | Unrecognized pension and other postretirement costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,730	3,697
CECONY | Future income tax
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	2,325	2,232
CECONY | Environmental remediation costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	711	800
CECONY | Revenue taxes
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	280	240
CECONY | Deferred storm costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	3	110
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	42	46
CECONY | Unamortized loss on reacquired debt
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	41	48
CECONY | Recoverable energy costs
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	38	15
Regulatory assets – current	4	18
CECONY | Pension and other postretirement benefits deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	7	16
CECONY | O&R property tax reconciliation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	0
CECONY | Surcharge for New York State assessment
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	26	40
CECONY | Preferred stock redemption
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	25	26
CECONY | Net electric deferrals
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	24	44
CECONY | O&R transition bond charges
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	0	0
CECONY | Workers’ compensation
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	13	11
CECONY | Other
Regulatory Assets [Line Items]
Regulatory assets – noncurrent	208	157
CECONY | Deferred derivative losses
Regulatory Assets [Line Items]
Regulatory assets – current	$ 86	$ 103

XML

Capitalization - Additional Information (Details)		12 Months Ended
		Dec. 31, 2016 USD ($) shares	Dec. 31, 2015 USD ($)
Schedule of Capitalization [Line Items]
Percentage limitation for income available for dividends (not more than)		100.00%
Rolling average calculation of income available for dividends (years)		2 years
Long-term debt, fair value		$ 16,093,000,000	$ 13,856,000,000
Long-term debt		14,774,000,000	12,745,000,000
Non-recourse debt		$ 845,000,000	339,000,000
Ratio of consolidated debt to consolidated total capital		0.51
Maximum
Schedule of Capitalization [Line Items]
Ratio of consolidated debt to consolidated total capital		0.65
Transition Bonds, Issued in 2004
Schedule of Capitalization [Line Items]
Long-term debt		$ 11,000,000	15,000,000
Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value		15,457,000,000
Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value		636,000,000
Tax-Exempt Debt
Schedule of Capitalization [Line Items]
Long-term debt	[1]	1,086,000,000	1,086,000,000
Notes
Schedule of Capitalization [Line Items]
Covenant principal balance amount limit		$ 100,000,000
Notes | Maximum
Schedule of Capitalization [Line Items]
Ratio of consolidated debt to consolidated total capital		0.675
Term Loan
Schedule of Capitalization [Line Items]
Covenant principal balance amount limit		$ 150,000,000
Term Loan | Maximum
Schedule of Capitalization [Line Items]
Ratio of consolidated debt to consolidated total capital		0.65
CECONY
Schedule of Capitalization [Line Items]
Common stock shares, outstanding | shares		21,976,200
Long-term debt, fair value		$ 13,268,000,000	12,427,000,000
Long-term debt		$ 12,073,000,000	11,437,000,000
Ratio of consolidated debt to consolidated total capital		0.52
CECONY | Maximum
Schedule of Capitalization [Line Items]
Ratio of consolidated debt to consolidated total capital		0.65
Covenant principal balance amount limit		$ 100,000,000
CECONY | Minimum
Schedule of Capitalization [Line Items]
Covenant principal balance amount limit		150,000,000
CECONY | Level 2
Schedule of Capitalization [Line Items]
Long-term debt, fair value		12,632,000,000
CECONY | Level 3
Schedule of Capitalization [Line Items]
Long-term debt, fair value		636,000,000
CECONY | Tax-Exempt Debt
Schedule of Capitalization [Line Items]
Tax-exempt debt issued, value		450,000,000
Long-term debt		1,086,000,000	$ 1,086,000,000
CECONY | Tax-Exempt Debt | Level 3
Schedule of Capitalization [Line Items]
Long-term debt		$ 636,000,000

[1] Rates are to be reset weekly or by auction held every 35 days; December 31, 2016 rates shown.

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Capitalization - Schedule of Long-Term Debt Maturities (Details) $ in Millions	Dec. 31, 2016 USD ($)
Debt Instrument [Line Items]
2017	$ 39
2018	1,688
2019	574
2020	388
2021	540
CECONY
Debt Instrument [Line Items]
2017	0
2018	1,200
2019	475
2020	350
2021	$ 0

XML

Capitalization - Carrying Amounts and Fair Values of Long-Term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Carrying Amount	$ 14,774	$ 12,745
Fair Value	16,093	13,856
CECONY
Debt Instrument [Line Items]
Carrying Amount	12,073	11,437
Fair Value	$ 13,268	$ 12,427

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Short-Term Borrowing (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Short-term Debt [Line Items]
Commercial paper, outstanding	$ 1,054,000,000	$ 1,529,000,000
Weighted average interest rate	1.00%	0.70%
Loans outstanding under credit agreement	$ 0	$ 0
Letters of credit outstanding under the Credit Agreement	$ 2,000,000	15,000,000
Ratio of consolidated debt to consolidated total capital	0.51
Minimum percentage of liens on assets	5.00%
Maximum
Short-term Debt [Line Items]
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	$ 600,000,000	$ 1,033,000,000
Weighted average interest rate	1.00%	0.70%
Letters of credit outstanding under the Credit Agreement	$ 2,000,000
Ratio of consolidated debt to consolidated total capital	0.52
CECONY | Maximum
Short-term Debt [Line Items]
Ratio of consolidated debt to consolidated total capital	0.65
CECONY | Revolving Credit
Short-term Debt [Line Items]
Maximum borrowing capacity	$ 2,250,000,000

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Pension Benefits - Total Periodic Benefit Costs (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	$ 275	$ 297	$ 227
Interest cost on projected benefit obligation	596	575	572
Expected return on plan assets	(947)	(886)	(832)
Recognition of net actuarial loss	596	775	618
Recognition of prior service costs	4	4	4
NET PERIODIC BENEFIT COST	524	765	589
Amortization of regulatory asset	0	1	2
TOTAL PERIODIC BENEFIT COST	524	766	591
Cost capitalized	(214)	(301)	(225)
Reconciliation to rate level	54	(74)	118
Cost charged to operating expenses	364	391	484
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost – including administrative expenses	258	279	211
Interest cost on projected benefit obligation	559	538	536
Expected return on plan assets	(898)	(840)	(789)
Recognition of net actuarial loss	565	734	586
Recognition of prior service costs	2	2	2
NET PERIODIC BENEFIT COST	486	713	546
Amortization of regulatory asset	0	1	2
TOTAL PERIODIC BENEFIT COST	486	714	548
Cost capitalized	(203)	(285)	(212)
Reconciliation to rate level	58	(74)	108
Cost charged to operating expenses	$ 341	355	444
Increase in CECONY's pension obligation		$ 45	$ 45

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Pension Benefits - Schedule of Funded Status (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$ 14,377	$ 15,081	$ 12,197
Service cost – excluding administrative expenses	271	293	221
Interest cost on projected benefit obligation	596	575	572
Net actuarial (gain)/loss	(302)	(996)	2,641
Plan amendments	(256)	0	6
Benefits paid	(591)	(576)	(556)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	14,095	14,377	15,081
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	11,759	11,495	10,755
Actual return on plan assets	829	126	752
Employer contributions	508	750	578
Benefits paid	(591)	(576)	(556)
Administrative expenses	(33)	(36)	(34)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	12,472	11,759	11,495
FUNDED STATUS	(1,623)	(2,618)	(3,586)
Unrecognized net loss	3,157	3,909	4,888
Unrecognized prior service costs	(244)	16	20
Accumulated benefit obligation	12,655	12,909	13,454
CECONY
CHANGE IN PROJECTED BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	13,482	14,137	11,429
Service cost – excluding administrative expenses	254	274	206
Interest cost on projected benefit obligation	559	538	536
Net actuarial (gain)/loss	(282)	(931)	2,484
Plan amendments	(259)	0	0
Benefits paid	(551)	(536)	(518)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	13,203	13,482	14,137
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	11,141	10,897	10,197
Actual return on plan assets	787	118	715
Employer contributions	469	697	535
Benefits paid	(551)	(536)	(518)
Administrative expenses	(31)	(35)	(32)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	11,815	11,141	10,897
FUNDED STATUS	(1,388)	(2,341)	(3,240)
Unrecognized net loss	2,995	3,704	4,616
Unrecognized prior service costs	(258)	3	4
Accumulated benefit obligation	$ 11,806	$ 12,055	$ 12,553

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Pension Benefits - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Pension liability	$ 995,000,000
Investments value	273,000,000	$ 243,000,000
Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	303,000,000	285,000,000
CECONY
Defined Benefit Plan Disclosure [Line Items]
Pension liability	953,000,000
Investments value	246,000,000	221,000,000
CECONY | Other Nonqualified Supplemental Defined Benefit Pension
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	268,000,000	249,000,000
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Decrease to regulatory assets	1,002,000,000
Charge to OCI	5,000,000
Net loss estimated to be amortized	579,000,000
Prior service cost estimated to be amortized	(16,000,000)
Accumulated benefit obligation	12,655,000,000	12,909,000,000	$ 13,454,000,000
Defined benefit plan, bond amount (excess of)	50,000,000
Estimated future employer contributions	$ 423,000,000
Increase in pension benefit obligation			800,000,000
Pension Benefits | Minimum
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, percent of bond original price	50.00%
Defined benefit plan, bond yield (percent)	1.00%
Pension Benefits | Maximum
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, percent of bond original price	200.00%
Defined benefit plan, bond yield (percent)	20.00%
Pension Benefits | CECONY
Defined Benefit Plan Disclosure [Line Items]
Decrease to regulatory assets	$ 967,000,000
Charge to OCI	1,000,000
Net loss estimated to be amortized	548,000,000
Prior service cost estimated to be amortized	(18,000,000)
Accumulated benefit obligation	11,806,000,000	$ 12,055,000,000	$ 12,553,000,000
Estimated future employer contributions	$ 388,000,000

XML

Pension Benefits - Schedule of Assumptions (Details) - Pension Benefits	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Discount rate, benefit obligations	4.25%	4.25%	3.90%
Discount rate, net periodic benefit cost	4.25%	3.90%	4.80%
Expected return on plan assets	7.80%	7.80%	8.00%
CECONY
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	4.25%	4.25%	4.25%
Rate of compensation increase	4.25%	4.25%	4.35%
O&R
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	4.00%	4.00%	4.00%
Rate of compensation increase	4.00%	4.00%	4.25%

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Pension Benefits - Schedule of Expected Benefit Payments (Details) - Pension Benefits $ in Millions	Dec. 31, 2016 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2017	$ 702
2018	719
2019	730
2020	745
2021	758
2022-2026	3,990
CECONY
Defined Benefit Plan Disclosure [Line Items]
2017	653
2018	670
2019	679
2020	693
2021	705
2022-2026	$ 3,716

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Pension Benefits - Schedule of Plan Assets Allocations (Details) - Pension Benefits	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	100.00%	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range, Minimum	0.52%
Target Allocation Range, Maximum	0.64%
Plan Assets Percentage	58.00%	57.00%	58.00%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range, Minimum	0.28%
Target Allocation Range, Maximum	0.38%
Plan Assets Percentage	33.00%	33.00%	32.00%
Real Estate
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range, Minimum	7.00%
Target Allocation Range, Maximum	11.00%
Plan Assets Percentage	9.00%	10.00%	10.00%

XML

Pension Benefits - Schedule of Fair Value of Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Private Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets		$ 170
Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets		1,248
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Funds for retiree health benefits	$ (270)	(282)
Funds for retiree health benefits measured at NAV per share (l)(n)	(37)	(43)
Total funds for retiree health benefits	(307)	325
Investments (excluding funds for retiree health benefits)	12,910	12,223
Pending activities	(438)	(464)
Total fair value of plan net assets	12,472	11,759	$ 11,495	$ 10,755
Pension Benefits | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,466	3,106
Pension Benefits | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,558	3,220
Pension Benefits | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,337	2,222
Pension Benefits | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,140	1,356
Pension Benefits | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1	1
Pension Benefits | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	200	170
Pension Benefits | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	536	529
Pension Benefits | Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	364	293
Pension Benefits | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	11,602	10,897
Pension Benefits | Private Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	247
Pension Benefits | Real Estate
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,139
Pension Benefits | Hedge Funds
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	229	233
Pension Benefits | Investments Valued Using NAV Per Share
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,615	1,651
Pension Benefits | Level 1
Defined Benefit Plan Disclosure [Line Items]
Funds for retiree health benefits	(165)	(162)
Investments (excluding funds for retiree health benefits)	6,931	6,094
Pension Benefits | Level 1 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,466	3,106
Pension Benefits | Level 1 | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	3,187	2,874
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	147	115
Pension Benefits | Level 1 | Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	296	161
Pension Benefits | Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	7,096	6,256
Pension Benefits | Level 2
Defined Benefit Plan Disclosure [Line Items]
Funds for retiree health benefits	(105)	(120)
Investments (excluding funds for retiree health benefits)	4,401	4,521
Pension Benefits | Level 2 | U.S. Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0
Pension Benefits | Level 2 | International Equity
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	371	346
Pension Benefits | Level 2 | U.S. Government Issued Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1,337	2,222
Pension Benefits | Level 2 | Corporate Bonds Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	2,140	1,356
Pension Benefits | Level 2 | Structured Assets Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	1	1
Pension Benefits | Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	200	170
Pension Benefits | Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	389	414
Pension Benefits | Level 2 | Futures
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	68	132
Pension Benefits | Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 4,506	$ 4,641

XML

Pension Benefits - Schedule of Employer Contribution to Defined Savings Plan (Details) - Pension Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 36	$ 34	$ 32
CECONY
Defined Benefit Plan Disclosure [Line Items]
Employer contribution to the defined savings plan	$ 32	$ 29	$ 27

XML

Other Postretirement Benefits - Net Periodic Postretirement Benefit Costs (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 18	$ 20	$ 19
Interest cost on accumulated other postretirement benefit obligation	48	51	60
Expected return on plan assets	(77)	(78)	(77)
Recognition of net actuarial loss	5	31	57
Recognition of prior service cost	(20)	(20)	(19)
NET PERIODIC BENEFIT COST	(26)	4	40
Cost capitalized	11	(2)	(15)
Reconciliation to rate level	22	14	10
Cost charged to operating expenses	7	16	35
CECONY
Defined Benefit Plan Disclosure [Line Items]
Service cost	13	15	15
Interest cost on accumulated other postretirement benefit obligation	40	43	52
Expected return on plan assets	(67)	(68)	(68)
Recognition of net actuarial loss	3	28	51
Recognition of prior service cost	(14)	(14)	(15)
NET PERIODIC BENEFIT COST	(25)	4	35
Cost capitalized	10	(2)	(14)
Reconciliation to rate level	22	6	2
Cost charged to operating expenses	$ 7	$ 8	$ 23

XML

Other Postretirement Benefits - Schedule of Funded Status (Details) - Other Postretirement Benefits - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	$ 1,287	$ 1,411	$ 1,395
Service cost	18	20	19
Interest cost on accumulated other postretirement benefit obligation	48	51	60
Amendments	0	0	(12)
Net actuarial loss/(gain)	(57)	(103)	47
Benefits paid and administrative expenses	(134)	(127)	(134)
Participant contributions	36	35	36
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,198	1,287	1,411
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	994	1,084	1,113
Actual return on plan assets	60	(6)	59
Employer contributions	7	6	7
EGWP payments	35	28	12
Participant contributions	36	35	36
Benefits paid	(157)	(153)	(143)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	975	994	1,084
FUNDED STATUS	(223)	(293)	(327)
Unrecognized net loss/(gain)	(24)	28	78
Unrecognized prior service costs	(31)	(51)	(71)
CECONY
CHANGE IN BENEFIT OBLIGATION
Projected benefit obligation at beginning of year	1,093	1,203	1,198
Service cost	13	15	15
Interest cost on accumulated other postretirement benefit obligation	40	43	52
Amendments	0	0	0
Net actuarial loss/(gain)	(52)	(85)	28
Benefits paid and administrative expenses	(122)	(117)	(125)
Participant contributions	35	34	35
PROJECTED BENEFIT OBLIGATION AT END OF YEAR	1,007	1,093	1,203
CHANGE IN PLAN ASSETS
Fair value of plan assets at beginning of year	870	950	977
Actual return on plan assets	52	(4)	54
Employer contributions	7	6	7
EGWP payments	33	26	11
Participant contributions	35	34	35
Benefits paid	(146)	(142)	(134)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR	851	870	950
FUNDED STATUS	(156)	(223)	(253)
Unrecognized net loss/(gain)	(42)	4	45
Unrecognized prior service costs	$ (18)	$ (32)	$ (46)

XML

Other Postretirement Benefits - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2014
CECONY | Clean Energy Business and RECO
Defined Benefit Plan Disclosure [Line Items]
Credit to OCI (net of taxes) for unrecognized net losses	$ 2
Debit to OCI (net of taxes) for unrecognized prior service costs	1
CECONY | Clean Energy Businesses
Defined Benefit Plan Disclosure [Line Items]
Credit to OCI (net of taxes) for unrecognized net losses	1
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Decrease in liability for other postretirement benefits	70
Increase in regulatory liabilities	32
Net losses unrecognized to be amortized	4
Prior service cost estimated to be amortized	$ (17)
Health care cost trend rate for net periodic benefit cost, current	6.00%
Health care cost trend rate for net periodic benefit cost	4.50%
Health care cost trend rate for benefit obligations, current	5.80%
Health care cost trend rate for benefit obligations	4.50%
Expected contributions	$ 14
Other Postretirement Benefits | Maximum
Defined Benefit Plan Disclosure [Line Items]
Increase in postretirement benefit obligations (less than)		$ 10
Other Postretirement Benefits | CECONY
Defined Benefit Plan Disclosure [Line Items]
Decrease in liability for other postretirement benefits	67
Increase in regulatory liabilities	32
Net losses unrecognized to be amortized	1
Prior service cost estimated to be amortized	(11)
Expected contributions	$ 10

XML

Other Postretirement Benefits - Schedule of Actuarial Assumptions (Details) - Other Postretirement Benefits	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Expected Return on Plan Assets	7.00%	7.75%	7.75%
CECONY
Defined Benefit Plan Disclosure [Line Items]
Discount Rate, Benefit Obligations	4.00%	4.05%	3.75%
Discount Rate, Net Periodic Benefit Cost	4.05%	3.75%	4.50%
O&R
Defined Benefit Plan Disclosure [Line Items]
Discount Rate, Benefit Obligations	4.20%	4.20%	3.85%
Discount Rate, Net Periodic Benefit Cost	4.20%	3.85%	4.75%

XML

Other Postretirement Benefits - Schedule of Change of Assumed Health Care Cost Trend Rate (Details) - Other Postretirement Benefits $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($)
Increase
Effect on accumulated other postretirement benefit obligation	$ (4)
Effect on service cost and interest cost components for 2016	1
Decrease
Effect on accumulated other postretirement benefit obligation	26
Effect on service cost and interest cost components for 2016	0
CECONY
Increase
Effect on accumulated other postretirement benefit obligation	(24)
Effect on service cost and interest cost components for 2016	(1)
Decrease
Effect on accumulated other postretirement benefit obligation	41
Effect on service cost and interest cost components for 2016	$ 1

XML

Other Postretirement Benefits - Schedule of Expected Benefit Payments (Details) - Other Postretirement Benefits $ in Millions	Dec. 31, 2016 USD ($)
Defined Benefit Plan Disclosure [Line Items]
2017	$ 86
2018	85
2019	83
2020	80
2021	78
2022-2026	375
CECONY
Defined Benefit Plan Disclosure [Line Items]
2017	77
2018	75
2019	73
2020	70
2021	68
2022-2026	$ 322

XML

Other Postretirement Benefits - Schedule of Plan Assets Allocations (Details) - Other Postretirement Benefits - CECONY	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Plan Assets Percentage	100.00%	100.00%	100.00%
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range, Minimum	57.00%
Target Allocation Range, Maximum	73.00%
Plan Assets Percentage	60.00%	59.00%	59.00%
Debt Securities
Defined Benefit Plan Disclosure [Line Items]
Target Allocation Range, Minimum	26.00%
Target Allocation Range, Maximum	44.00%
Plan Assets Percentage	40.00%	41.00%	41.00%

XML

Other Postretirement Benefits - Schedule of Fair Values of Plan Assets (Details) - Other Postretirement Benefits - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Funds for retiree health benefits	$ 270	$ 282
Investments (including funds for retiree health benefits)	924	942
Funds for retiree health benefits measured at NAV per share (l)(n)	37	43
Pending activities	14	9
Total fair value of plan net assets	975	994	$ 1,084	$ 1,113
Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	391	393
Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	250	260
Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	13	7
Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	654	660
Level 1
Defined Benefit Plan Disclosure [Line Items]
Funds for retiree health benefits	165	162
Investments (including funds for retiree health benefits)	165	162
Level 1 | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Level 1 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Level 1 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Level 1 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	0	0
Level 2
Defined Benefit Plan Disclosure [Line Items]
Funds for retiree health benefits	105	120
Investments (including funds for retiree health benefits)	759	780
Level 2 | Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	391	393
Level 2 | Other Fixed Income Debt
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	250	260
Level 2 | Cash and Cash Equivalents
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	13	7
Level 2 | Total investments
Defined Benefit Plan Disclosure [Line Items]
Total fair value of plan net assets	$ 654	$ 660

XML

Environmental Matters - Accrued Liabilities and Regulatory Assets (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Site Contingency [Line Items]
Accrued Liabilities	$ 753	$ 765
Regulatory assets	7,124	8,228
Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	664	679
Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	89	86
Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	753	765
Regulatory assets	823	904
CECONY
Site Contingency [Line Items]
Accrued Liabilities	655	665
Regulatory assets	6,563	7,603
CECONY | Manufactured gas plant sites
Site Contingency [Line Items]
Accrued Liabilities	567	579
CECONY | Other Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	88	86
CECONY | Superfund Sites
Site Contingency [Line Items]
Accrued Liabilities	655	665
Regulatory assets	$ 711	$ 800

XML

Environmental Matters - Environmental Remediation Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Environmental Exit Cost [Line Items]
Remediation costs incurred	$ 34	$ 37
Insurance recoveries received	1	0
CECONY
Environmental Exit Cost [Line Items]
Remediation costs incurred	21	34
Insurance recoveries received	$ 1	$ 0

XML

Environmental Matters - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($)
Superfund Sites
Site Contingency [Line Items]
Remediation cost estimate	$ 55
Superfund Sites | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	$ 2,800
CECONY | Asbestos Proceedings
Site Contingency [Line Items]
Estimated undiscounted asbestos liability (years)	15 years
CECONY | Superfund Sites
Site Contingency [Line Items]
Remediation cost estimate	$ 47
CECONY | Superfund Sites | Manufactured Gas Plant Sites | Maximum
Site Contingency [Line Items]
Estimated aggregate undiscounted potential liability related environmental contaminants (up to)	$ 2,600

XML

Environmental Matters - Accrued Liability for Asbestos Suits and Workers' Compensation Proceedings (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Site Contingency [Line Items]
Regulatory assets	$ 7,124	$ 8,228
Asbestos Suits
Site Contingency [Line Items]
Accrued liability	8	8
Regulatory assets	8	8
Workers' Compensation
Site Contingency [Line Items]
Accrued liability	88	86
Regulatory assets	13	11
CECONY
Site Contingency [Line Items]
Regulatory assets	6,563	7,603
CECONY | Asbestos Suits
Site Contingency [Line Items]
Accrued liability	7	7
Regulatory assets	7	7
CECONY | Workers' Compensation
Site Contingency [Line Items]
Accrued liability	83	81
Regulatory assets	$ 13	$ 11

XML

Other Material Contingencies - Additional Information (Details) $ in Millions		1 Months Ended	12 Months Ended
	Mar. 12, 2014 building people	Jul. 31, 2007 lawsuit person	Dec. 31, 2016 USD ($) lawsuit	Dec. 31, 2015 USD ($)	Dec. 31, 2014
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 2,370	$ 2,856
Payment Guarantee by CET Electric of Contributions to New York Transco LLC
Guarantor Obligations [Line Items]
Ownership interest, percentage					45.70%
Estimated project cost percentage			175.00%
Financial Guarantee in Behalf of CET Gas for Proposed Gas Transmission Project
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			$ 25
Financial and Performance Guarantee for Commodity Transactions During Period in which Con Edison Solutions Provides Transition Services
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			42
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
Certain Obligations Under Agreement to Sell the Retail Electric Supply Business
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			53
Financial Guarantee to Public Utility Commission of Texas
Guarantor Obligations [Line Items]
Guarantee obligations maximum exposure			5
Manhattan Steam Main Rupture | CECONY
Guarantor Obligations [Line Items]
Number of person who died in stream rupture incident | person		1
Number of pending lawsuits | lawsuit		60
Estimated accrued liability for suits			25
Insurance receivable for suits			$ 25
Manhattan Explosion and Fire
Guarantor Obligations [Line Items]
Number of pending lawsuits | lawsuit			70
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

XML

Other Material Contingencies - Total Guarantees (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 2,370	$ 2,856
Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,048
Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	736
Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	458
Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	128
0 – 3 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	1,605
0 – 3 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	435
0 – 3 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	603
0 – 3 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	439
0 – 3 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	128
4 – 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	648
4 – 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	613
4 – 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	35
4 – 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
4 – 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
Greater than 10 years
Guarantor Obligations [Line Items]
Total guarantees, by type and term	117
Greater than 10 years | Con Edison Transmission
Guarantor Obligations [Line Items]
Total guarantees, by type and term	0
Greater than 10 years | Energy transactions
Guarantor Obligations [Line Items]
Total guarantees, by type and term	98
Greater than 10 years | Renewable electric production projects
Guarantor Obligations [Line Items]
Total guarantees, by type and term	19
Greater than 10 years | Other
Guarantor Obligations [Line Items]
Total guarantees, by type and term	$ 0

XML

Electricity Purchase Agreements - Summary of Significant Terms of Electricity Purchase Agreements (Details)	12 Months Ended
	Dec. 31, 2016 MW
Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	322
Contracted Output (MW)	293
Contract Term (Years)	40 years
Linden Cogeneration
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	974
Contracted Output (MW)	630
Contract Term (Years)	25 years
Indian Point
Long-term Contract for Purchase of Electric Power [Line Items]
Plant Output (MW)	2,150
Contracted Output (MW)	500
Contract Term (Years)	16 years

XML

Electricity Purchase Agreements - Summary of Estimated Capacity and Other Fixed Payments (Details) $ in Millions	Dec. 31, 2016 USD ($)
Long-term Contract for Purchase of Electric Power [Line Items]
2017	$ 178
2018	125
2019	120
2020	76
2021	54
All Years Thereafter	710
CECONY
Long-term Contract for Purchase of Electric Power [Line Items]
2017	178
2018	125
2019	119
2020	75
2021	54
All Years Thereafter	$ 710

XML

Electricity Purchase Agreements - Summary of Capacity, Energy and Other Fixed Payments (Details) - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 692	$ 865	$ 1,312
Linden Cogeneration
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	304	323	381
Indian Point
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	203	226	247
Astoria Energy
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	50	178	230
Astoria Generating Company
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	16	0	0
Brooklyn Navy Yard
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	119	113	133
Indeck Corinth
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	0	25	80
Selkirk
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	0	0	144
Independence
Long-term Contract for Purchase of Electric Power [Line Items]
Capacity, energy and other fixed payments	$ 0	$ 0	$ 97

XML

Leases - Schedule of Capital Leases (Details) - Common - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Property Subject to or Available for Operating Lease [Line Items]
Utility Plant	$ 3	$ 3
CECONY
Property Subject to or Available for Operating Lease [Line Items]
Utility Plant	$ 2	$ 2

XML

Leases - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Operating Leased Assets [Line Items]
Accumulated amortization	$ 3	$ 3
CECONY
Operating Leased Assets [Line Items]
Accumulated amortization	$ 1	$ 2
Increase in annual payments, percentage	2.18%
Decrease in transformer installations, percentage	0.50%

XML

Leases - Future Minimum Lease Commitments (Details) $ in Millions	Dec. 31, 2016 USD ($)
Capital Leased Assets [Line Items]
2017	$ 1
2018	1
2019	0
2020	0
2021	0
All years thereafter	0
Total	2
Less: amount representing interest	0
Present value of net minimum lease payment	2
CECONY
Capital Leased Assets [Line Items]
2017	1
2018	1
2019	0
2020	0
2021	0
All years thereafter	0
Total	2
Less: amount representing interest	0
Present value of net minimum lease payment	$ 2

XML

Leases - Future Minimum Rental Payments for Operating Leases (Details) $ in Millions	Dec. 31, 2016 USD ($)
Operating Leased Assets [Line Items]
2017	$ 61
2018	62
2019	61
2020	61
2021	58
All years thereafter	788
Total	1,091
CECONY
Operating Leased Assets [Line Items]
2017	53
2018	54
2019	54
2020	54
2021	53
All years thereafter	696
Total	$ 964

XML

Goodwill and Other Intangible Assets (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($) business_acquisition	Dec. 31, 2015 USD ($) business_acquisition
Goodwill [Line Items]
Goodwill	$ 428	$ 429
Impairment charge	15
Finite lived intangible assets, accumulated amortization	6	4
Amortization of Intangible Assets	2
Intangibles Future Amortization:
Year 1	8
Year 2	8
Year 3	8
Year 4	8
Year 5	8
Other Intangible Assets
Goodwill [Line Items]
Finite lived intangible assets, net	5	2
Finite lived intangible assets, accumulated amortization	5	4
O&R Merger
Goodwill [Line Items]
Goodwill	$ 406	406
Energy Service and Gas Storage Companies
Goodwill [Line Items]
Goodwill		$ 23
Number of businesses acquired included in goodwill impairment test | business_acquisition	2	2
Impairment charge	$ 15
Impairment charge, net of tax	12
Power Purchase
Goodwill [Line Items]
Finite lived intangible assets, net	119
Finite lived intangible assets, accumulated amortization	1
CECONY
Goodwill [Line Items]
Goodwill	245	$ 245
O&R
Goodwill [Line Items]
Goodwill	161	$ 161
Con Edison Solutions and Con Edison Development | Energy Service and Gas Storage Companies
Goodwill [Line Items]
Goodwill	$ 23
Con Edison Solutions | Energy Service and Gas Storage Companies
Goodwill [Line Items]
Number of businesses acquired included in goodwill impairment test | business_acquisition	2
Con Edison Solutions | Residential Solar Company
Goodwill [Line Items]
Goodwill	$ 14

XML

Income Tax - Schedule of Components of Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
State
Current	$ (42)	$ 38	$ 59
Deferred	188	93	61
Federal
Current	(43)	(86)	(9)
Deferred	604	569	463
Amortization of investment tax credits	(9)	(9)	(6)
Total income tax expense	698	605	568
CECONY
State
Current	(1)	48	66
Deferred	114	82	65
Federal
Current	59	77	158
Deferred	435	372	271
Amortization of investment tax credits	(4)	(5)	(5)
Total income tax expense	$ 603	$ 574	$ 555

XML

Income Tax - Schedule of Differences on Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Deferred tax liabilities:
Property basis differences	$ 9,446	$ 8,614
Regulatory assets:
Unrecognized pension and other postretirement costs	1,162	1,562
Future income tax	986	947
Environmental remediation costs	333	365
Deferred storm costs	23	75
Other regulatory assets	371	367
Equity investments	363	295
Total deferred tax liabilities	12,684	12,225
Deferred tax assets:
Accrued pension and other postretirement costs	581	982
Regulatory liabilities	822	836
Superfund and other environmental costs	304	308
Asset retirement obligations	99	97
Loss carryforwards	59	29
Tax credits carryforward	498	258
Valuation allowance	(16)	(15)
Other	303	362
Total deferred tax assets	2,650	2,857
Net deferred tax liabilities	10,034	9,368
Unamortized investment tax credits	171	169
Net deferred tax liabilities and unamortized investment tax credits	10,205	9,537
CECONY
Deferred tax liabilities:
Property basis differences	8,620	7,922
Regulatory assets:
Unrecognized pension and other postretirement costs	1,104	1,490
Future income tax	940	899
Environmental remediation costs	287	322
Deferred storm costs	1	45
Other regulatory assets	321	308
Equity investments	0	0
Total deferred tax liabilities	11,273	10,986
Deferred tax assets:
Accrued pension and other postretirement costs	467	857
Regulatory liabilities	728	752
Superfund and other environmental costs	265	268
Asset retirement obligations	92	94
Loss carryforwards	0	0
Tax credits carryforward	0	1
Valuation allowance	0	0
Other	312	292
Total deferred tax assets	1,864	2,264
Net deferred tax liabilities	9,409	8,722
Unamortized investment tax credits	41	33
Net deferred tax liabilities and unamortized investment tax credits	$ 9,450	$ 8,755

XML

Income Tax - Schedule of Income Tax Reconciliation (Details)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
STATUTORY TAX RATE
Federal	35.00%	35.00%	35.00%
Changes in computed taxes resulting from:
State income tax	4.00%	5.00%	5.00%
Cost of removal	(1.00%)	(5.00%)	(5.00%)
Renewable energy credits	(1.00%)	(1.00%)	(0.00%)
Research and development credits	(1.00%)	0.00%	0.00%
Other	0.00%	0.00%	(1.00%)
Effective tax rate	36.00%	34.00%	34.00%
CECONY
STATUTORY TAX RATE
Federal	35.00%	35.00%	35.00%
Changes in computed taxes resulting from:
State income tax	4.00%	5.00%	5.00%
Cost of removal	(1.00%)	(5.00%)	(5.00%)
Renewable energy credits	(0.00%)	(0.00%)	(0.00%)
Research and development credits	(1.00%)	0.00%	0.00%
Other	(1.00%)	0.00%	(1.00%)
Effective tax rate	36.00%	35.00%	34.00%

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Income Tax - Additional Information (Details)	1 Months Ended			12 Months Ended
	Feb. 29, 2016 USD ($)	Jan. 31, 2016 USD ($)	Jan. 31, 2015 USD ($)	Dec. 31, 2016 USD ($) claim	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards, accelerated bonus depreciation				$ 32,000,000
Valuation allowance				207,000,000
Deferred tax asset, valuation allowance				16,000,000	$ 15,000,000
Deferred tax assets, charitable contribution carryforwards				$ 6,000,000	5,000,000
Corporate franchise tax rate				6.50%		7.10%
Decrease in accumulated deferred tax liabilities				$ 74,000,000
Decrease in regulatory asset				11,000,000
Increase in regulatory liability				62,000,000
Income tax refund requested		$ 160,000,000	$ 224,000,000
Income tax refund	$ 160,000,000
Decrease in uncertain tax positions resulting from settlement of claims filed in previous years				0	0	$ 0
Uncertain tax position from investment tax credit claim				19,000,000	1,000,000	27,000,000
Effective income tax rate reconciliation, uncertainty of taxes				35,000,000
Effective income tax rate reconciliation, uncertainty net of federal taxes				24,000,000
Change in effective tax rate upon completion of ongoing tax examinations				21,000,000
Change in effective tax rate upon completion of ongoing tax examinations, net of taxes				14,000,000
Unrecognized tax benefits that would have an impact on effective tax rate				24,000,000
Unrecognized tax benefits that would have an impact on effective tax rate, net of taxes				17,000,000
Penalties for uncertain tax positions				0	0	0
Amount of interest and penalties in their consolidated balance sheets				0	0
New York State
Operating Loss Carryforwards [Line Items]
Decrease in effective tax rate resulting from tax settlement				8,000,000
CECONY
Operating Loss Carryforwards [Line Items]
Deferred tax asset, valuation allowance				0	0
Decrease in accumulated deferred tax liabilities				69,000,000
Decrease in regulatory asset				10,000,000
Increase in regulatory liability				59,000,000
Income tax refund requested			$ 128,000,000
Income tax refund	$ 143,000,000
Decrease in uncertain tax positions resulting from settlement of claims filed in previous years				0	0	0
Uncertain tax position from investment tax credit claim				19,000,000	0	$ 2,000,000
Effective income tax rate reconciliation, uncertainty of taxes				17,000,000
Effective income tax rate reconciliation, uncertainty net of federal taxes				12,000,000
Change in effective tax rate upon completion of ongoing tax examinations				2,000,000
Unrecognized tax benefits that would have an impact on effective tax rate				3,000,000
CECONY | New York State
Operating Loss Carryforwards [Line Items]
Decrease in effective tax rate resulting from tax settlement				2,000,000
Charitable Contribution
Operating Loss Carryforwards [Line Items]
Deferred tax asset, valuation allowance					$ 3,000,000
General Business Tax Credit
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards				31,000,000
Renewable Energy Tax Credits
Operating Loss Carryforwards [Line Items]
Valuation allowance				498,000,000
Tax credit carryforward, valuation allowance				0
Charitable Contribution
Operating Loss Carryforwards [Line Items]
Tax credit carryforward, valuation allowance				0
Federal
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards				204,000,000
Federal | Carryback to 2007 and 2014
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards				178,000,000
Federal | Year 2036
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards				26,000,000
New York City
Operating Loss Carryforwards [Line Items]
Deferred tax asset, valuation allowance				12,000,000
State
Operating Loss Carryforwards [Line Items]
Deferred tax asset, valuation allowance				$ 4,000,000
State | New York State
Operating Loss Carryforwards [Line Items]
Number of claims settled | claim				2
Decrease in uncertain tax positions resulting from settlement of claims filed in previous years				$ 11,000,000
Decrease in effective tax rate resulting from tax settlement, net of taxes				5,000,000
Uncertain tax position from investment tax credit claim				21,000,000
State | CECONY | New York State
Operating Loss Carryforwards [Line Items]
Decrease in effective tax rate resulting from tax settlement, net of taxes				$ 1,000,000

XML

Income Tax - Summary of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	$ 34	$ 34	$ 9
Additions based on tax positions related to the current year	2	0	0
Additions based on tax positions of prior years	19	1	27
Reductions for tax positions of prior years	(13)	0	(2)
Reductions from expiration of statute of limitations	0	(1)	0
Settlements	0	0	0
Balance at end of period	42	34	34
CECONY
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of period	2	2	0
Additions based on tax positions related to the current year	2	0	0
Additions based on tax positions of prior years	19	0	2
Reductions for tax positions of prior years	(2)	0	0
Reductions from expiration of statute of limitations	0	0	0
Settlements	0	0	0
Balance at end of period	$ 21	$ 2	$ 2

XML

Stock-Based Compensation - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Income tax benefit realized from stock options exercised	$ 20,000,000	$ 14,000,000	$ 12,000,000
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	$ 18,000,000	12,000,000	10,000,000
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period (years)	3 years
Income tax benefit realized from stock options exercised	$ 1,000,000	$ 1,000,000	$ 1,000,000
Stock Options | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award expiration period (years)	10 years
Performance RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock received upon vesting (shares)	1
Compensation expense to be recognized	$ 34,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
Performance RSUs | CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense to be recognized	$ 27,000,000
Nonvested awards, compensation cost not yet recognized, period for recognition (years)	1 year
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
Weighted average grant date price per share (in dollars per share)	$ 76.62
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
Weighted average grant date price per share (in dollars per share)	$ 76.62
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)	$ 83.16
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)	$ 82.73
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)	$ 72.10
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)	$ 72.34
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units issued	27,600
Weighted average grant date price per share (in dollars per share)	$ 74.37
Stock Purchase Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares purchased on the open market	720,268	761,784	708,276
Weighted average share price per share, on shares purchased on open market	$ 72.67	$ 62.75	$ 56.23

XML

Stock-Based Compensation - Stock-Based Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 50	$ 34	$ 29
Income tax benefit	20	14	12
Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	42	27	22
Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	1	2
Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	2
Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	4	4	3
CECONY
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	44	29	26
Income tax benefit	18	12	10
CECONY | Performance-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	36	23	19
CECONY | Time-based restricted stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	1	2
CECONY | Non-employee director deferred stock compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	2	2	2
CECONY | Stock purchase plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 4	$ 3	$ 3

XML

Stock-Based Compensation - Summary of Status of Stock Options (Details)	12 Months Ended
	Dec. 31, 2016 $ / shares shares
Shares
Outstanding at beginning of period (in shares) | shares	79,125
Exercised (in shares) | shares	79,125
Forfeited (in shares) | shares	0
Outstanding at end of period (in shares) | shares	0
Weighted Average Exercise Price
Outstanding at beginning of period (in dollars per share) | $ / shares	$ 43.50
Exercised (in dollars per share) | $ / shares	43.50
Forfeited (in dollars per share) | $ / shares	0.00
Outstanding at end of period (in dollars per share) | $ / shares	$ 0.00
CECONY
Shares
Outstanding at beginning of period (in shares) | shares	65,775
Exercised (in shares) | shares	65,775
Forfeited (in shares) | shares	0
Outstanding at end of period (in shares) | shares	0
Weighted Average Exercise Price
Outstanding at beginning of period (in dollars per share) | $ / shares	$ 43.50
Exercised (in dollars per share) | $ / shares	43.50
Forfeited (in dollars per share) | $ / shares	0.00
Outstanding at end of period (in dollars per share) | $ / shares	$ 0.00

XML

Stock-Based Compensation - Summary of Stock Options (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Aggregate intrinsic value
Options outstanding	$ 0	$ 2
Options exercised	2	3
Cash received by Con Edison for payment of exercise price	3	6
CECONY
Aggregate intrinsic value
Options outstanding	0	1
Options exercised	2	3
Cash received by Con Edison for payment of exercise price	$ 3	$ 5

XML

Stock-Based Compensation - Assumptions Used to Calculate Fair Value (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate, minimum	0.85%	0.64%	0.23%
Risk-free interest rate, maximum	1.20%	3.28%	3.07%
Expected term (years)	3 years	3 years	3 years
Expected share price volatility, minimum (percent)	17.72%
Expected share price volatility, maximum (percent)	18.22%
Expected share price volatility (percent)		15.82%	13.14%

XML

Stock-Based Compensation - Summary of Changes in Status of Performance RSUs' (Details) - Performance RSUs	12 Months Ended
	Dec. 31, 2016 $ / shares shares
Units
Non-vested at beginning of period (in units) | shares	1,078,339
Granted (in units) | shares	386,400
Vested (in units) | shares	(351,230)
Forfeited (in units) | shares	(26,372)
Non-vested at end of period (in units) | shares	1,087,137
CECONY
Units
Non-vested at beginning of period (in units) | shares	853,257
Granted (in units) | shares	295,300
Vested (in units) | shares	(285,162)
Forfeited (in units) | shares	(15,053)
Non-vested at end of period (in units) | shares	848,342
TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	$ 45.26
Granted (in dollars per share)	83.16
Vested (in dollars per share)	55.16
Forfeited (in dollars per share)	48.48
Non-vested at end of period (in dollars per share)	$ 55.45
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)	$ 45.37
Granted (in dollars per share)	82.73
Vested (in dollars per share)	55.21
Forfeited (in dollars per share)	53.61
Non-vested at end of period (in dollars per share)	54.92
Non-TSR Portion
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share)	58.08
Granted (in dollars per share)	72.10
Vested (in dollars per share)	57.96
Forfeited (in dollars per share)	61.03
Non-vested at end of period (in dollars per share)	$ 63.03
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)	$ 58.12
Granted (in dollars per share)	72.34
Vested (in dollars per share)	58.07
Forfeited (in dollars per share)	63.05
Non-vested at end of period (in dollars per share)	$ 63.00

XML

Stock-Based Compensation - Summary of Changes in Status of Time-Based Awards (Details) - Time-based Awards	12 Months Ended
	Dec. 31, 2016 $ / shares shares
Units
Non-vested at beginning of period (in units) | shares	64,980
Granted (in units) | shares	23,000
Vested (in units) | shares	(20,900)
Forfeited (in units) | shares	(1,100)
Non-vested at end of period (in units) | shares	65,980
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 58.56
Granted (in dollars per share) | $ / shares	76.62
Vested (in dollars per share) | $ / shares	61.03
Forfeited (in dollars per share) | $ / shares	60.13
Non-vested at end of period (in dollars per share) | $ / shares	$ 64.04
CECONY
Units
Non-vested at beginning of period (in units) | shares	61,630
Granted (in units) | shares	21,800
Vested (in units) | shares	(19,800)
Forfeited (in units) | shares	(1,050)
Non-vested at end of period (in units) | shares	62,580
Weighted Average Grant Date Fair Value
Non-vested at beginning of period (in dollars per share) | $ / shares	$ 58.55
Granted (in dollars per share) | $ / shares	76.62
Vested (in dollars per share) | $ / shares	61.03
Forfeited (in dollars per share) | $ / shares	60.43
Non-vested at end of period (in dollars per share) | $ / shares	$ 64.03

XML

Financial Information by Business Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Revenues	$ 12,075	$ 12,554	$ 12,919
Depreciation and amortization	1,216	1,130	1,071
Operating income	2,575	2,427	2,209
Other Income (deductions)	64	24	42
Interest charges	696	653	591
Income taxes on operating income	714	644	589
Total assets	48,255	45,642	44,071
Capital expenditures	5,235	3,418	2,721
Income taxes on non-operating income	16	40	21
New Accounting Pronouncement, Early Adoption, Effect
Segment Reporting Information [Line Items]
Total assets			237
CECONY
Segment Reporting Information [Line Items]
Revenues	10,165	10,328	10,786
Depreciation and amortization	1,106	1,040	991
Operating income	2,262	2,247	2,139
Other Income (deductions)	0	(5)	11
Interest charges	603	584	537
Total assets	40,856	40,230
Income taxes on non-operating income	14	14	7
Operating segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	1,091	1,383	1,244
Depreciation and amortization	42	22	19
Operating income	183	58	(60)
Other Income (deductions)	21	35	28
Interest charges	34	11	(8)
Income taxes on operating income	53	22	(8)
Total assets	2,551	1,680	1,013
Capital expenditures	1,235	823	447
Operating segment | Con Edison Transmission
Segment Reporting Information [Line Items]
Revenues	0	0	0
Depreciation and amortization	0	0	0
Operating income	(3)	0	0
Other Income (deductions)	43	0	0
Interest charges	6	0	0
Income taxes on operating income	0	0	0
Total assets	1,150	3	1
Capital expenditures	1,078	0	0
Operating segment | CECONY
Segment Reporting Information [Line Items]
Revenues	10,165	10,328	10,786
Depreciation and amortization	1,106	1,040	991
Operating income	2,262	2,247	2,139
Other Income (deductions)	0	(5)	11
Interest charges	603	584	537
Income taxes on operating income	617	588	562
Total assets	40,856	40,230	39,443
Capital expenditures	2,756	2,435	2,132
Operating segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	8,106	8,172	8,437
Depreciation and amortization	865	820	781
Operating income	1,847	1,798	1,712
Other Income (deductions)	2	(2)	8
Interest charges	459	447	412
Income taxes on operating income	495	447	425
Total assets	30,708	30,603	30,295
Capital expenditures	1,819	1,658	1,500
Operating segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	1,508	1,527	1,721
Depreciation and amortization	159	142	132
Operating income	357	356	314
Other Income (deductions)	(1)	(2)	2
Interest charges	105	96	89
Income taxes on operating income	92	100	88
Total assets	7,553	6,974	6,478
Capital expenditures	811	671	549
Operating segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	551	629	628
Depreciation and amortization	82	78	78
Operating income	58	93	113
Other Income (deductions)	(1)	(1)	1
Interest charges	39	41	36
Income taxes on operating income	30	41	49
Total assets	2,595	2,653	2,670
Capital expenditures	126	106	83
Operating segment | O&R
Segment Reporting Information [Line Items]
Revenues	821	845	892
Depreciation and amortization	67	68	61
Operating income	130	121	128
Other Income (deductions)	1	(4)	3
Interest charges	36	35	35
Income taxes on operating income	40	33	35
Total assets	2,758	2,719	2,810
Capital expenditures	166	160	142
Operating segment | O&R | Electric
Segment Reporting Information [Line Items]
Revenues	637	663	680
Depreciation and amortization	49	50	46
Operating income	95	103	103
Other Income (deductions)	1	(2)	3
Interest charges	24	23	24
Income taxes on operating income	30	31	29
Total assets	1,949	2,140	2,023
Capital expenditures	114	114	105
Operating segment | O&R | Gas
Segment Reporting Information [Line Items]
Revenues	184	182	212
Depreciation and amortization	18	18	15
Operating income	35	18	25
Other Income (deductions)	0	(2)	0
Interest charges	12	12	10
Income taxes on operating income	10	2	6
Total assets	809	579	786
Capital expenditures	52	46	37
Other
Segment Reporting Information [Line Items]
Revenues	(2)	(2)	(3)
Depreciation and amortization	1	0	0
Operating income	3	1	2
Other Income (deductions)	(1)	(2)	0
Interest charges	17	23	27
Income taxes on operating income	4	1	0
Total assets	940	1,010	804
Capital expenditures	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	1
Income taxes on operating income	0	0	0
Total assets	0	0	1
Capital expenditures	0	0	0
Inter-segment
Segment Reporting Information [Line Items]
Revenues	(7)	2	10
Inter-segment | Clean Energy Businesses
Segment Reporting Information [Line Items]
Revenues	7	(2)	(10)
Inter-segment | CECONY
Segment Reporting Information [Line Items]
Revenues	(111)	(110)	(106)
Inter-segment | CECONY | Electric
Segment Reporting Information [Line Items]
Revenues	17	18	16
Inter-segment | CECONY | Gas
Segment Reporting Information [Line Items]
Revenues	6	6	6
Inter-segment | CECONY | Steam
Segment Reporting Information [Line Items]
Revenues	$ 88	$ 86	$ 84

XML

Derivative Instruments and Hedging Activities - Fair Values of Commodity Derivatives Including Offsetting of Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	$ 363	$ 345
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(117)	(183)
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	(99)	(207)
Gross Amounts Offset	6	46
Net Amounts of Assets/ (Liabilities)	(93)	(161)
Margin deposits	7	26
Interest Rate Swap
Fair value of derivative liabilities
Net Amounts of Assets/ (Liabilities)	(1)	0
CECONY
Fair value of derivative assets
Net Amounts of Assets/ (Liabilities)	326	311
Net fair value derivative assets/(liabilities)
Gross Amounts of Recognized Assets/ (Liabilities)	(95)	(125)
Gross Amounts Offset	9	48
Net Amounts of Assets/ (Liabilities)	(86)	(77)
Margin deposits	7	26
Fair Value of Derivative Liabilities, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(138)	(144)
Gross Amounts Offset	61	78
Net Amounts of Assets/ (Liabilities)	(77)	(66)
Fair Value of Derivative Liabilities, Current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(111)	(121)
Gross Amounts Offset	45	71
Net Amounts of Assets/ (Liabilities)	(66)	(50)
Fair Value of Derivative Liabilities, Liabilities Held For Sale, Current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	0	(115)
Gross Amounts Offset	0	50
Net Amounts of Assets/ (Liabilities)	0	(65)
Fair Value of Derivative Liabilities, Non-current
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(91)	(102)
Gross Amounts Offset	52	63
Net Amounts of Assets/ (Liabilities)	(39)	(39)
Fair Value of Derivative Liabilities, Non-current | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(77)	(92)
Gross Amounts Offset	44	56
Net Amounts of Assets/ (Liabilities)	(33)	(36)
Fair Value of Derivative Liabilities, Liabilities Held For Sale, Noncurrent
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	0	(28)
Gross Amounts Offset	0	15
Net Amounts of Assets/ (Liabilities)	0	(13)
Fair Value of Derivative Liabilities
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(229)	(389)
Gross Amounts Offset	113	206
Net Amounts of Assets/ (Liabilities)	(116)	(183)
Fair Value of Derivative Liabilities | CECONY
Fair value of derivative liabilities
Gross Amounts of Recognized Assets/ (Liabilities)	(188)	(213)
Gross Amounts Offset	89	127
Net Amounts of Assets/ (Liabilities)	(99)	(86)
Fair Value of Derivative Assets, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	81	59
Gross Amounts Offset	(64)	(41)
Net Amounts of Assets/ (Liabilities)	17	18
Fair Value of Derivative Assets, Current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	52	40
Gross Amounts Offset	(45)	(32)
Net Amounts of Assets/ (Liabilities)	7	8
Fair Value of Derivative Assets, Assets Held for Sale, Current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	0	51
Gross Amounts Offset	0	(50)
Net Amounts of Assets/ (Liabilities)	0	1
Fair Value of Derivative Assets, Non-current
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	49	57
Gross Amounts Offset	(43)	(54)
Net Amounts of Assets/ (Liabilities)	6	3
Fair Value of Derivative Assets, Non-current | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	41	48
Gross Amounts Offset	(35)	(47)
Net Amounts of Assets/ (Liabilities)	6	1
Fair Value of Derivative Assets, Assets Held for Sale, Noncurrent
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	0	15
Gross Amounts Offset	0	(15)
Net Amounts of Assets/ (Liabilities)	0	0
Fair Value of Derivative Assets
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	130	182
Gross Amounts Offset	(107)	(160)
Net Amounts of Assets/ (Liabilities)	23	22
Fair Value of Derivative Assets | CECONY
Fair value of derivative assets
Gross Amounts of Recognized Assets/ (Liabilities)	93	88
Gross Amounts Offset	(80)	(79)
Net Amounts of Assets/ (Liabilities)	$ 13	$ 9

XML

Derivative Instruments and Hedging Activities - Additional Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	$ 62
Makeup of net credit exposure with commodity exchange brokers	25
Makeup of net credit exposure with investment-grade counterparties	17
Makeup of net credit exposure independent system operators	9
Makeup of net credit exposure non-investment grade/non-rated counterparties	11
Derivative liabilities	117	$ 183
Interest Rate Swap
Investment Holdings [Line Items]
Derivative liabilities	1	$ 0
CECONY
Investment Holdings [Line Items]
Energy supply and hedging activities credit exposure total	20
Makeup of net credit exposure with commodity exchange brokers	14
Makeup of net credit exposure with investment-grade counterparties	$ 6
Clean Energy Businesses | Coram | Interest Rate Swap
Investment Holdings [Line Items]
Derivative, fixed interest rate	2.0855%
Derivative liabilities	$ 1

XML

Derivative Instruments and Hedging Activities - Realized and Unrealized Gains or Losses on Commodity Derivatives (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ 24	$ 2
Total deferred gains/(losses)	(188)	(177)
Net deferred gains/(losses)	(164)	(175)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(203)	(186)
Purchased power expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(101)	(109)
Unrealized gain/(loss) on derivatives	11	(1)
Gas purchased for resale
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	(112)	(106)
Non-utility revenue
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	9	30
Other operations and maintenance expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	1	(1)
Unrealized gain/(loss) on derivatives	1	(1)
Non-utility operating revenue
Pre-tax gain/(loss) recognized in income
Unrealized gain/(loss) on derivatives	(5)	1
Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	23	1
Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	1	1
Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	22	(16)
Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(212)	(136)
Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	2	(25)
CECONY
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	20	2
Total deferred gains/(losses)	(172)	(161)
Net deferred gains/(losses)	(152)	(159)
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	1	(1)
CECONY | Purchased power expense
Pre-tax gain/(loss) recognized in income
Total pre-tax gain/(loss) recognized in income	0	0
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	1	(1)
Unrealized gain/(loss) on derivatives	1	(1)
CECONY | Deferred Derivative Gains,Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	18	2
CECONY | Deferred Derivative Gains, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	2	0
CECONY | Deferred Derivative Losses, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	18	(11)
CECONY | Recoverable Energy Costs, Current
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	(194)	(127)
CECONY | Deferred Derivative Losses, Noncurrent
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Total deferred gains/(losses)	$ 4	$ (23)

XML

Derivative Instruments and Hedging Activities - Hedged Volume of Derivative Transactions (Details) gal in Thousands	Dec. 31, 2016 MW MMBTU gal MWh
Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	21,235,830
Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	13,616
Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	77,248,786
Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	3,696
CECONY | Electric Energy
Derivatives, Fair Value [Line Items]
Notional amount | MWh	19,258,400
CECONY | Capacity
Derivatives, Fair Value [Line Items]
Notional amount | MW	7,500
CECONY | Natural Gas
Derivatives, Fair Value [Line Items]
Notional amount | MMBTU	71,060,000
CECONY | Refined Fuels
Derivatives, Fair Value [Line Items]
Notional amount | gal	3,696

XML

Derivative Instruments and Hedging Activities - Aggregate Fair Value of Companies' Derivative Instruments with Credit-Risk-Related Contingent Features (Details) $ in Millions	Dec. 31, 2016 USD ($)
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	$ 113
Collateral posted	43
Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	11
Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	75
Derivatives in net asset position additional collateral	15
Additional Collateral Required Due To Loss Of Unsecured Credit
Derivatives, Fair Value [Line Items]
Collateral posted	43
CECONY
Derivatives, Fair Value [Line Items]
Aggregate fair value – net liabilities	103
Collateral posted	42
CECONY | Downgrade One Level from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	10
CECONY | Downgrade to Below Investment Grade from Current Ratings
Derivatives, Fair Value [Line Items]
Additional collateral	$ 65

XML

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on Recurring Basis (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 363	$ 345
Derivative liabilities	117	183
CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	326	311
Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(24)	(56)
Derivative liabilities	(38)	(128)
Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(10)	17
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	236	187
Derivative liabilities	4	17
Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	210	172
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	144	200
Derivative liabilities	145	286
Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	125	114
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	7	14
Derivative liabilities	6	8
Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	8
Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	30	47
Derivative liabilities	116	105
Commodity | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	20	35
Derivative liabilities	99	86
Commodity | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(24)	7
Derivative liabilities	(38)	(65)
Commodity | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	(10)	17
Derivative liabilities	(26)	(57)
Commodity | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	14	2
Derivative liabilities	4	16
Commodity | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	10	1
Derivative liabilities	1	14
Commodity | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	33	25
Derivative liabilities	144	153
Commodity | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	19	9
Derivative liabilities	124	129
Commodity | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	7	13
Derivative liabilities	6	1
Commodity | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1	8
Derivative liabilities	0	0
Interest Rate Swap
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	1	0
Interest Rate Swap | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Interest Rate Swap | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Interest Rate Swap | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	1	0
Interest Rate Swap | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Commodity Held For Sale
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	1
Derivative liabilities	0	78
Commodity Held For Sale | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	(63)
Derivative liabilities	0	(63)
Commodity Held For Sale | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0	1
Commodity Held For Sale | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	63
Derivative liabilities	0	133
Commodity Held For Sale | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	1
Derivative liabilities	0	7
Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	333	297
Other | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	306	276
Other | Netting Adjustment
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Other | Netting Adjustment | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Other | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	222	185
Other | Level 1 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	200	171
Other | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	111	112
Other | Level 2 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	106	105
Other | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Other | Level 3 | CECONY
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 0	$ 0

XML

Fair Value Measurements - Schedule of Commodity Derivatives (Details) - Level 3 $ in Millions	12 Months Ended
	Dec. 31, 2016 USD ($) $ / MWh $ / kW-month
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives | $	$ 1
Electricity
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives | $	$ (1)
Electricity | Forward Energy Prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWh/Dt) | $ / MWh	37.75
Electricity | Forward Energy Prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWh/Dt) | $ / MWh	55.00
Electricity | Forward Capacity Prices | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWh/Dt) | $ / kW-month	2.42
Electricity | Forward Capacity Prices | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per MWh/Dt) | $ / kW-month	10.25
Transmission Congestion Contracts/Financial Transmission Rights
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives | $	$ 2
Transmission Congestion Contracts/Financial Transmission Rights | Discount for Inter Zonal Forward Price Curves
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (percent)	50.00%
Transmission Congestion Contracts/Financial Transmission Rights | Discount for Historical Monthly Realized Settlements | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (percent)	(75.20%)
Transmission Congestion Contracts/Financial Transmission Rights | Discount for Historical Monthly Realized Settlements | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (percent)	58.90%
Transmission Congestion Contracts/Financial Transmission Rights | Inter Zonal Forward Price Curves Adjusted for Historical Zonal Losses | Minimum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per kW-month) | $ / MWh	1.11
Transmission Congestion Contracts/Financial Transmission Rights | Inter Zonal Forward Price Curves Adjusted for Historical Zonal Losses | Maximum
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (dollar per kW-month) | $ / MWh	2.90
Transmission Congestion Contracts | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value of commodity derivatives | $	$ 1
Transmission Congestion Contracts | Discount for Inter Zonal Forward Price Curves | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (percent)	50.00%
Transmission Congestion Contracts | Discount for Historical Monthly Realized Settlements | Minimum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (percent)	(75.20%)
Transmission Congestion Contracts | Discount for Historical Monthly Realized Settlements | Maximum | CECONY
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Unobservable Inputs Range (percent)	58.90%

XML

Fair Value Measurements - Additional Information (Details) - Purchased power expense - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair value, assets measured on recurring basis, change in unrealized loss	$ 1	$ 8
Clean Energy Businesses
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Loss on Level 3 energy derivative liabilities	$ 6	$ 14

XML

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, 2016	Dec. 31, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	$ 6	$ 20
Included in earnings	(7)	(20)
Included in regulatory assets and liabilities	(6)	1
Purchases	4	11
Sales	4	0
Settlements	0	(6)
Ending Balance	1	6
CECONY
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning Balance	8	13
Included in earnings	(1)	(6)
Included in regulatory assets and liabilities	(6)	0
Purchases	2	5
Sales	0	0
Settlements	(2)	(4)
Ending Balance	$ 1	$ 8

XML

Variable Interest Entities - Additional Information (Details) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2016 USD ($) VIE	Dec. 31, 2015 USD ($) MW
Variable Interest Entity [Line Items]
Noncontrolling interest		$ 8	$ 9
Variable Interest Entity, Primary Beneficiary | Texas Solar 4
Variable Interest Entity [Line Items]
Percentage of variable interests	80.00%	80.00%
VIE consolidated, carrying amount, assets and liabilities, net		$ 54	58
Noncontrolling Interest
Variable Interest Entity [Line Items]
Noncontrolling interest		$ 7	$ 9
Texas | Variable Interest Entity, Primary Beneficiary | Texas Solar 4
Variable Interest Entity [Line Items]
Generating capacity (MW AC) | MW			40
CECONY
Variable Interest Entity [Line Items]
Number of potential VIEs, long-term electricity purchase agreements | VIE		2

XML

Variable Interest Entities - Net Assets of Texas Solar 4 (Details) - Texas Solar 4 - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Restricted cash	$ 8	$ 9
Receivable from parent company	35	32
Non-utility property, less accumulated depreciation of $9 and $5, respectively	104	107
Other assets	8	11
Total assets	155	159
Long-term debt due within one year	3	2
Other liabilities	38	37
Long-term debt	60	62
Total liabilities	101	101
Accumulated depreciation	$ 9	$ 5

XML

Variable Interest Entities - Summary of VIEs (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2016 USD ($) MW
Variable Interest Entity, Not Primary Beneficiary | Copper Mountain Solar 3 | Nevada
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW		128
Power Purchase Agreement Term in Years		20 years
Maximum Exposure to Loss		$ 179,000,000
Variable Interest Entity, Not Primary Beneficiary | Mesquite Solar 1 | Arizona
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW		83
Power Purchase Agreement Term in Years		20 years
Maximum Exposure to Loss		$ 108,000,000
Variable Interest Entity, Not Primary Beneficiary | Copper Mountain Solar 2 | Nevada
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW		75
Power Purchase Agreement Term in Years		25 years
Maximum Exposure to Loss		$ 84,000,000
Variable Interest Entity, Not Primary Beneficiary | California Solar | California
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW		55
Power Purchase Agreement Term in Years		25 years
Maximum Exposure to Loss		$ 69,000,000
Variable Interest Entity, Not Primary Beneficiary | Broken Bow II | Nebraska
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW		38
Power Purchase Agreement Term in Years		25 years
Maximum Exposure to Loss		$ 48,000,000
Variable Interest Entity, Primary Beneficiary | Texas Solar 4
Variable Interest Entity [Line Items]
Percentage of variable interests	80.00%	80.00%
Maximum exposure for consolidated investments		$ 7,000,000
Variable Interest Entity, Primary Beneficiary | Texas Solar 4 | Texas
Variable Interest Entity [Line Items]
Generating Capacity Owned (MW AC) | MW		32
Power Purchase Agreement Term in Years		25 years
Maximum Exposure to Loss		$ 47,000,000
Variable Interest Entity, Not Primary Beneficiary, Aggregated Disclosure
Variable Interest Entity [Line Items]
Percentage of variable interests		50.00%

XML

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	$ 246	$ 242
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	29
Asset retirement obligations, accretion expense	10
Asset retirement obligations, liabilities settled	35
Asset retirement obligations, reductions	37	23
CECONY
Regulatory Liabilities [Line Items]
Accrued liability - asset retirement obligations	227	234
Increase in liabilities for asset retirement obligations due to changes in estimated cash flows	19
Asset retirement obligations, accretion expense	9
Asset retirement obligations, liabilities settled	35
Asset retirement obligations, reductions	$ 37	$ 23

XML

Related Party Transactions - Summary of Costs of Administrative and Other Services Provided and Received (Details) - CECONY - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
Cost of services provided	$ 108	$ 99	$ 90
Cost of services received	$ 64	$ 60	$ 57

XML

Related Party Transactions - Additional Information (Details)	7 Months Ended	12 Months Ended
	Dec. 31, 2016 USD ($)	Dec. 31, 2016 USD ($) agreement	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Jan. 31, 2016
Related Party Transaction [Line Items]
Gas purchased for resale		$ 477,000,000	$ 495,000,000	$ 811,000,000
CECONY
Related Party Transaction [Line Items]
Sale of natural gas		47,000,000	54,000,000	80,000,000
Gas purchased for resale		319,000,000	337,000,000	$ 609,000,000
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 | Stagecoach | Purchased Power Costs
Related Party Transaction [Line Items]
Gas purchased for resale	$ 18,000,000
CECONY | Equity Method Investee | Stagecoach | Purchased Power Costs | Clean Energy Businesses
Related Party Transaction [Line Items]
Number of electricity sales agreements entered into | agreement		2
CET Electric
Related Party Transaction [Line Items]
Ownership interest, percentage	45.70%	45.70%			45.70%
O&R
Related Party Transaction [Line Items]
Outstanding loans to O&R		$ 0	$ 0

XML

Acquisitions, Investments and Dispositions - Texas Solar 7 (Details) - Texas Solar 7 - Texas $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2016 USD ($) MW	Dec. 31, 2016 USD ($)
Business Acquisition [Line Items]
Percentage of voting interest acquired	100.00%
Generating capacity (MW AC) | MW	106
Payments to acquire business	$ 227
Non-utility construction work in progress	218
Receivable from parent company	$ 9
Net assets		$ 127
Intangible assets		$ 41

XML

Acquisitions, Investments and Dispositions - Mountain Valley Pipeline (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2016	Dec. 31, 2018	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity method investment			$ 488	$ 574
Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Percentage of equity interest acquired	12.50%
Payments to acquire equity interest	$ 18
Equity method investment			$ 48
Mountain Valley Pipeline | Gas | Minimum | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity interest		$ 3,000
Mountain Valley Pipeline | Gas | Maximum | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity interest		$ 3,500

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Acquisitions, Investments and Dispositions - NY Transco (Details) - USD ($) $ in Millions	1 Months Ended
	May 31, 2016	Dec. 31, 2016	Jan. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity method investment		$ 488		$ 574
CET Electric
Schedule of Equity Method Investments [Line Items]
Ownership interest, percentage		45.70%	45.70%
CET Electric | Equity Method Investee | Purchase Price of TOTS Project Transfer
Schedule of Equity Method Investments [Line Items]
Purchase price	$ 122
CET Electric | Equity Method Investee | TOTS Project, Lease Payments
Schedule of Equity Method Investments [Line Items]
Payment for easement rights	$ 8
CET Electric | NY Transco
Schedule of Equity Method Investments [Line Items]
Equity method investment		$ 51

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Acquisitions, Investments and Dispositions - Stagecoach Gas Services (Details) - USD ($) $ in Millions	1 Months Ended
	Jun. 30, 2016	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity method investment		$ 488	$ 574
Stagecoach Gas Services
Schedule of Equity Method Investments [Line Items]
Percentage of equity interest acquired	50.00%
Payments to acquire equity interest	$ 974
Equity method investment		$ 992

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Acquisitions, Investments and Dispositions - Pilesgrove (Details) $ in Millions	1 Months Ended		9 Months Ended
	Aug. 31, 2016 USD ($)	Jun. 30, 2016 USD ($)	Sep. 30, 2016 MW	Dec. 31, 2016 USD ($)
Pilesgrove
Business Acquisition [Line Items]
Percentage of voting interest acquired	50.00%
Purchase price	$ 16
Bargain purchase gain	8
Bargain purchase gain, net of taxes	5
Non-utility property	45
Other current assets	$ 3
Pilesgrove | New Jersey
Business Acquisition [Line Items]
Net assets				$ 45
Pilesgrove
Business Acquisition [Line Items]
Equity method investment, impairment charge		$ 8
Equity method investment, impairment charge, net of taxes		$ 5
Percentage of equity interest owned		50.00%
Pilesgrove | New Jersey
Business Acquisition [Line Items]
Generating capacity (MW AC) | MW			18

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Acquisitions, Investments and Dispositions - Panoche Valley (Details) - Panoche Valley - California $ in Millions	1 Months Ended
	Oct. 31, 2016 USD ($) MW	Dec. 31, 2016 USD ($)
Business Acquisition [Line Items]
Percentage of equity interest owned	50.00%
Percentage of voting interest acquired	50.00%
Generating capacity (MW AC) | MW	240
Cash consideration	$ 28
Outstanding note payable relieved at acquisition	242
Non-utility construction work in progress	290
Other assets	22
Current liabilities	$ 14
Net assets		$ 388

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Acquisitions, Investments and Dispositions - Coram Wind (Details) - Coram Wind - California $ in Millions	1 Months Ended
	Dec. 31, 2016 USD ($) MW
Business Acquisition [Line Items]
Percentage of voting interest acquired	100.00%
Generating capacity (MW AC) | MW	102
Purchase price	$ 97
Non-utility property	191
Intangible assets	78
Restricted cash, current	8
Long-term debt	180
Net assets	$ 96

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Acquisitions, Investments and Dispositions - Pike County Light & Power Company (Details) - Pike - USD ($) $ in Millions		1 Months Ended	12 Months Ended
	Sep. 30, 2015	Aug. 31, 2016	Dec. 31, 2015
Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture of business		$ 15
Discontinued Operations, Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment charge on assets held for sale	$ 5		$ 5
Impairment of long-lived assets to be disposed of, net of tax	$ 3
Assets held for sale			23
Liabilities held for sale			$ 5
O&R | Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Period for transition services (up to)		18 months
Agreement to purchase and sell, term		3 years
Agreement to purchase and sell, term of extension option		3 years

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Acquisitions, Investments and Dispositions - Con Edison Solutions' Retail Electric Supply Business (Details) - Retail Electric Supply Business - USD ($) $ in Millions	1 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture of business	$ 235
Gain on sale of business	104
Gain on sale of business, after tax	56
Gain on sale of derivatives	65
Gain on sale of derivatives, after tax	42
Tax effect of sale, state tax related to change in apportionment of state income taxes	16
Tax effect of sale, state tax related to change in apportionment of state income taxes, net of federal tax	$ 10
Discontinued Operations, Held-for-sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale		$ 134
Liabilities held for sale		$ 84

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Schedule I - Condensed Financial Information - Condensed Statement of Income and Comprehensive Income (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Income Statements,Captions [Line Items]
Interest expense	$ (696)	$ (653)	$ (591)
NET INCOME	1,245	1,193	1,092
Comprehensive Income	$ 1,252	$ 1,204	$ 1,072
Net Income Per Share – Basic (dollars per share)	$ 4.15	$ 4.07	$ 3.73
Net Income Per Share – Diluted (dollars per share)	4.12	4.05	3.71
Dividends Declared Per Share (dollars per share)	$ 2.68	$ 2.60	$ 2.52
Average Number Of Shares Outstanding—Basic (In Millions)	300.4	293.0	292.9
Average Number Of Shares Outstanding—Diluted (In Millions)	301.9	294.4	294.0
Consolidated Edison, Inc.
Condensed Income Statements,Captions [Line Items]
Equity in earnings of subsidiaries	$ 1,254	$ 1,195	$ 1,101
Other income (deductions), net of taxes	32	27	19
Interest expense	(41)	(29)	(28)
NET INCOME	1,245	1,193	1,092
Comprehensive Income	$ 1,252	$ 1,204	$ 1,072
Net Income Per Share – Basic (dollars per share)	$ 4.15	$ 4.07	$ 3.73
Net Income Per Share – Diluted (dollars per share)	4.12	4.05	3.71
Dividends Declared Per Share (dollars per share)	$ 2.68	$ 2.60	$ 2.52
Average Number Of Shares Outstanding—Basic (In Millions)	300.4	293.0	292.9
Average Number Of Shares Outstanding—Diluted (In Millions)	301.9	294.4	294.0

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Schedule I - Condensed Financial Information - Condensed Statement of Cash Flows (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	$ 1,245	$ 1,193	$ 1,092
Change in Assets:
Income taxes receivable	87	58	(224)
Other – net	54	(27)	316
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,459	3,277	2,831
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(4,976)	(3,657)	(2,759)
FINANCING ACTIVITIES
Net proceeds of short-term debt	(475)	729	(651)
Issuance of long-term debt	2,590	1,147	1,850
Retirement of long-term debt	(735)	(500)	(480)
Debt issuance costs	(24)	(15)	(17)
Issuance of common shares for stock plans, net of repurchases	51	1	(10)
Issuance of common shares - public offering	702	0	0
Common stock dividends	(763)	(733)	(739)
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	1,345	629	(47)
NET CHANGE FOR THE PERIOD	(172)	249	25
BALANCE AT BEGINNING OF PERIOD	944	699	674
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	776	944	699
CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,056	1,084	1,058
Change in Assets:
Other – net	(11)	38	48
NET CASH FLOWS FROM OPERATING ACTIVITIES	3,038	2,819	2,430
INVESTING ACTIVITIES
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,739)	(2,638)	(2,304)
FINANCING ACTIVITIES
Net proceeds of short-term debt	(433)	583	(760)
Issuance of long-term debt	1,300	650	1,850
Retirement of long-term debt	(650)	(350)	(475)
Debt issuance costs	(13)	(7)	(17)
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	(440)	17	(114)
NET CHANGE FOR THE PERIOD	(141)	198	12
BALANCE AT BEGINNING OF PERIOD	843	645	633
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	702	843	645
Consolidated Edison, Inc.
Condensed Cash Flow Statements, Captions [Line Items]
Net Income	1,245	1,193	1,092
Equity in earnings of subsidiaries	(1,254)	(1,195)	(1,101)
Change in Assets:
Special deposits	0	0	314
Income taxes receivable	87	58	(224)
Other – net	(152)	(382)	(199)
NET CASH FLOWS FROM OPERATING ACTIVITIES	723	635	642
INVESTING ACTIVITIES
Contributions to subsidiaries	(691)	(15)	(1)
Long term debt receivable from affiliated companies	(900)	0	0
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(1,591)	(15)	(1)
FINANCING ACTIVITIES
Net proceeds of short-term debt	(53)	162	101
Issuance of long-term debt	900	0	0
Retirement of long-term debt	(2)	(2)	(2)
Debt issuance costs	(5)	0	0
Issuance of common shares for stock plans, net of repurchases	51	1	(10)
Issuance of common shares - public offering	702	0	0
Common stock dividends	(763)	(733)	(739)
NET CASH FLOWS FROM/(USED IN) FINANCING ACTIVITIES	830	(572)	(650)
NET CHANGE FOR THE PERIOD	(38)	48	(9)
BALANCE AT BEGINNING OF PERIOD	51	3	12
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	13	51	3
Consolidated Edison, Inc. | CECONY
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	744	872	712
Consolidated Edison, Inc. | O&R
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	43	81	40
Consolidated Edison, Inc. | Clean Energy Businesses
Condensed Cash Flow Statements, Captions [Line Items]
Dividends received	$ 10	$ 8	$ 8

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Schedule I - Condensed Financial Information - Condensed Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
CURRENT ASSETS
Cash and temporary cash investments	$ 776	$ 944	$ 699	$ 674
Accounts receivable – other	1,106	1,052
Income taxes receivable	79	166
Prepayments	159	177
Other current assets	205	194
TOTAL CURRENT ASSETS	3,406	3,836
Investments in subsidiaries	1,921	884
Goodwill	428	429
Other noncurrent assets	7,712	8,713
TOTAL ASSETS	48,255	45,642	44,071
CURRENT LIABILITIES
Long-term debt due within one year	39	739
Notes payable	1,054	1,529
Accounts Payable	1,147	1,008
Accrued taxes	64	62
Other current liabilities	297	335
TOTAL CURRENT LIABILITIES	3,843	4,720
Long-term debt	14,735	12,006
Shareholders’ Equity
Equity	14,298	13,052
TOTAL LIABILITIES AND EQUITY	48,255	45,642
Consolidated Edison, Inc.
CURRENT ASSETS
Cash and temporary cash investments	13	51	$ 3	$ 12
Special deposits	1	1
Accounts receivable – other	0	4
Income taxes receivable	79	166
Accounts receivable from affiliated companies	702	517
Prepayments	24	34
Other current assets	18	17
TOTAL CURRENT ASSETS	837	790
Investments in subsidiaries	13,991	12,737
Goodwill	406	406
Deferred income tax	42	11
Long term debt receivable from affiliated companies	900	0
Other noncurrent assets	16	7
TOTAL ASSETS	16,192	13,951
CURRENT LIABILITIES
Long-term debt due within one year	2	2
Notes payable	384	437
Accounts Payable	1	0
Accounts payable to affiliated companies	288	146
Accrued taxes	7	0
Other current liabilities	14	10
TOTAL CURRENT LIABILITIES	696	595
Total Liabilities	696	595
Long-term debt	1,198	304
Shareholders’ Equity
Common stock, including additional paid-in capital	5,887	5,062
Retained earnings	8,411	7,990
Equity	14,298	13,052
TOTAL LIABILITIES AND EQUITY	$ 16,192	$ 13,951

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Schedule II - Valuation and Qualifying Accounts (Details) - Allowance For Uncollectible Accounts - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 96	$ 106	$ 103
Charged To Costs And Expenses	63	77	98
Charged To Other Accounts	0	0	0
Deductions	76	87	95
Balance At End of Period	83	96	106
CECONY
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	91	98	95
Charged To Costs And Expenses	57	69	91
Charged To Other Accounts	0	0	0
Deductions	70	76	88
Balance At End of Period	$ 78	$ 91	$ 98