10-K 1 ed-20151231x10k.htm 10-K 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, 2015
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. x
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, 2015, was approximately $17.0 billion.
As of January 29, 2016, Con Edison had outstanding 293,589,401 Common Shares ($.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 16, 2016, to be filed with the Commission pursuant to Regulation 14A, not later than 120 days after December 31, 2015, 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.
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.
CET Electric
 
Consolidated Edison Transmission, LLC
CET Gas
 
Con Edison Gas Midstream, 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
PAPUC
 
Pennsylvania Public Utility Commission
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
 
 
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

4




 
Units of Measure
 
 
AC
 
Alternating current
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
 
Advance 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
 
Item 1:
Item 1A:
Item 1B:
Item 2:
Item 3:
Item 4:
 
 
 
Item 5:
Item 6:
Item 7:
Item 7A:
Item 8:
Item 9:
Item 9A:
Item 9B:
 
 
Item 10:
Item 11:
Item 12:
Item 13:
Item 14:
 
 
Item 15:
 

6




Introduction
This introduction contains certain information about Con Edison and its subsidiaries, including CECONY, 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:
 
CECONY, which delivers electricity, natural gas and steam to customers in New York City and Westchester County;
Orange & Rockland Utilities, Inc. (O&R) (together with CECONY referred to as the Utilities), which delivers electricity and natural gas to customers primarily located in southeastern New York, and northern New Jersey and northeastern Pennsylvania;
Competitive energy businesses, which sell to retail customers electricity purchased in wholesale markets and enter into related hedging transactions; provide energy-related products and services to wholesale and retail customers, and develop, own and operate renewable and energy infrastructure projects; and
Con Edison Transmission, Inc. (Con Edison Transmission), which invests in electric and gas transmission projects.
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 the capital and other costs of the company’s energy delivery systems. The Utilities recover from their full-service customers (who purchase electricity from the company), 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)
2011
 
2012
 
2013
 
2014
 
2015
 
Operating revenues
$12,886
 
$12,188
 
$12,354
 
$12,919
 
$12,554
 
Energy costs
5,001
 
3,887
 
4,054
 
4,513
 
3,716
 
Operating income
2,239
 
2,339
 
2,244
 
2,209
 
2,427
 
Net income
1,062
 
1,141
 
1,062
(b)
1,092
 
1,193
 
Total assets (f)(g)
38,873
 
40,845
(a)
40,451
(c)
44,071
(d)
45,642
(e)
Long-term debt (f)
10,068
 
9,994
 
10,415
 
11,546
 
12,006
 
Total equity
11,649
 
11,869
 
12,245
 
12,585
 
13,061
 
Net Income per common share – basic
$3.59
 
$3.88
 
$3.62
 
$3.73
 
$4.07
 
Net Income per common share – diluted
$3.57
 
$3.86
 
$3.61
 
$3.71
 
$4.05
 
Dividends declared per common share
$2.40
 
$2.42
 
$2.46
 
$2.52
 
$2.60
 
Book value per share
$39.05
 
$40.53
 
$41.81
 
$42.97
 
$44.50
 
Average common shares outstanding (millions)
293
 
293
 
293
 
293
 
293
 
Stock price low
$48.55
 
$53.63
 
$54.33
 
$52.23
 
$56.86
 
Stock price high
$62.74
 
$65.98
 
$63.66
 
$68.92
 
$72.25
 
(a)
Reflects a $1,846 million increase in net plant and a $304 million increase in regulatory assets for deferred storm costs.
(b)
Reflects a charge to earnings of $95 million (after taxes of $63 million) relating to the LILO transactions. See “Lease In/Lease Out Transactions” in Note J to the financial statements in Item 8.
(c)
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.
(d)
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.
(e)
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



(f)
Reflects $75 million, $68 million, $74 million and $85 million in 2011, 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.” See Note C to the financial statements in Item 8.
(g)
Reflects $266 million, $296 million, $122 million and $152 million in 2011, 2012, 2013, 2014, respectively, related to the adoption of ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes.” See Note L to the financial statements in Item 8.

CECONY 
  
For the Year Ended December 31,
(Millions of Dollars)
2011
 
2012
 
2013
 
2014
 
2015
 
Operating revenues
$10,432
 
$10,187
 
$10,430
 
$10,786
 
$10,328
 
Energy costs
3,243
 
2,665
 
2,873
 
2,985
 
2,304
 
Operating income
2,083
 
2,093
 
2,060
 
2,139
 
2,247
 
Net income
978
 
1,014
 
1,020
 
1,058
 
1,084
 
Total assets (e)(f)
34,994
 
36,630
(a)
36,095
(b)
39,443
(c)
40,230
(d)
Long-term debt (e)
9,153
 
9,083
 
9,303
 
10,788
 
10,787
 
Shareholder’s equity
10,431
 
10,552
 
10,847
 
11,188
 
11,415
 
(a)
Reflects a $1,243 million increase in net plant and a $229 million increase in regulatory assets for deferred storm costs.
(b)
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.
(c)
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.
(d)
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.
(e)
Reflects $67 million, $62 million, $63 million and $76 million in 2011, 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.” See Note C to the financial statements in Item 8.
(f)
Reflects $157 million, $193 million, $100 million and $118 million in 2011, 2012, 2013 and 2014, respectively, related to the adoption of ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes.” See Note L to the financial statements in Item 8.

Significant 2015 Developments and Outlook
Con Edison reported 2015 net income of $1,193 million or $4.07 a share compared with $1,092 million or $3.73 a share in 2014. Adjusted earnings were $1,196 million or $4.08 a share in 2015 compared with $1,140 million or $3.89 a share in 2014. See “Results of Operations” in Item 7 and “Non-GAAP Financial Measure” below.
In 2015, the Utilities invested $2,595 million to upgrade and reinforce their energy delivery systems, and the competitive energy businesses invested $823 million in renewable electric production projects. In 2016, the Companies are expected to invest $3,168 million for their energy delivery systems and $985 million in renewable electric production projects. Con Edison plans to meet its 2016 capital requirements, including for maturing securities, through internally-generated funds and the issuance of securities. The company’s plans include the issuance of between $1,000 million and $1,500 million of long-term debt 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 $200 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 June 2015, Con Edison initiated a plan to sell the retail electric supply business of its competitive energy businesses. In October 2015 O&R entered into an agreement to sell Pike to Corning Natural Gas Holding Corporation. 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 0.8 percent. O&R forecasts average annual growth of the peak demand in its service area over the next five years at design conditions for electric and gas to be approximately 0.3 percent and 0.6 percent, respectively. See “The Utilities” in Item 1.
In September 2015, CECONY, the New York State Public Service Commission (NYSPSC) staff and others entered into a Joint Proposal to settle the proceeding the NYSPSC commenced in February 2009 to examine the prudence of certain CECONY expenditures and related matters. Pursuant to the Joint Proposal, which is subject  to NYSPSC approval, the company is required to credit $116 million to customers and, for the period

8




2017 through 2044, to not seek to recover from customers an aggregate $55 million relating to return on its capital expenditures. In addition, the company’s revenues that were made subject to potential refund in this proceeding would no longer be subject to refund. See “Other Regulatory Matters” in Note B to the financial statements in Item 8 .
In June 2015, the National Transportation Safety Board determined that the probable cause of a March 2014 explosion and fire, in which eight people died and more than 50 people were injured, 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 CECONY that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a New York 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. 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 the incident and to review the prudence of the company’s conduct associated with the incident. In December 2015, the company responded that the NYSPSC should not institute the proceedings and disputed the alleged violations. See “Other Regulatory Matters” in Note B and “Manhattan Explosion and Fire” in Note H to the financial statements in Item 8.
In 2015, the NYSPSC adopted Joint Proposals with respect to CECONY’s rates for electric delivery service for 2016 and O&R’s rates for electric and gas delivery service through October 2017 and 2018, respectively; the 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; and the NYSPSC continued its proceeding to investigate the practices of qualifying persons to perform plastic fusions on gas facilities. See “Utility Regulation” in Item 1 and Note B to the financial statements in Item 8.
In January 2016, CECONY filed a request with the NYSPSC for electric and gas rate increases of $482 million and $154 million, respectively, effective January 2017. The filing reflects a return on common equity of 9.75 percent and a common equity ratio of 48 percent. 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 Investor Information section of Con Edison’s website also 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 (which Con Edison formerly referred to as earnings from ongoing operations) 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 competitive 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)
2011
2012
2013
2014
2015
Reported net income – GAAP basis
$1,051
$1,138
$1,062
$1,092
$1,193
Impairment of assets held for sale (a)




3
Gain on sale of solar electric production projects (b)



(26)

Loss from LILO transactions (c)


95
1

Net mark-to-market effects of the competitive energy businesses (d)
13
(40)
(45)
73

Adjusted earnings
$1,064
$1,098
$1,112
$1,140
$1,196
Reported earnings per share – GAAP basis (basic)
$3.59
$3.88
$3.62
$3.73
$4.07
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 competitive energy businesses
0.05
(0.13)
(0.14)
0.25

Adjusted earnings per share
$3.64
$3.75
$3.80
$3.89
$4.08
(a)
An impairment charge of $3 million, after taxes of $2 million, was recorded related to O&R's wholly-owned subsidiary, Pike County Light & Power Company (Pike).
(b)
After taxes of $19 million.
(c)
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. See Note J to the financial statements in Item 8.
(d)
After taxes of $9 million, $29 million, $30 million and $55 million for the years ended December 31, 2011 through 2014, respectively.


10




Item 1:    Business

Contents of Item 1
Page
 


11



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), the competitive energy businesses and Con Edison Transmission, Inc. (Con Edison Transmission). 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 and the competitive energy businesses. 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 competitive energy businesses sell electricity to retail customers, provide energy-related products and services, and develop, own and operate renewable and energy infrastructure projects.
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 22,000 MMlb of steam annually to approximately 1,700 customers in parts of Manhattan.
O&R
Electric
O&R and its utility subsidiaries, Rockland Electric Company (RECO) and Pike County Light & Power Company (Pike) (together referred to herein as O&R) provide electric service to approximately 0.3 million customers in southeastern New York and in adjacent areas of northern New Jersey and northeastern Pennsylvania, an approximately 1,350 square mile service area.


13



Gas
O&R delivers gas to over 0.1 million customers in southeastern New York and adjacent areas of northeastern Pennsylvania.

Assets Held for Sale
In October 2015, O&R entered into an agreement to sell Pike to Corning Natural Gas Holding Corporation (see
Note U to the financial statements in Item 8).

Competitive Energy Businesses
Con Edison pursues competitive energy opportunities through three wholly-owned subsidiaries: Con Edison Solutions, Con Edison Energy and Con Edison Development. These businesses sell to retail customers electricity purchased in wholesale markets and enter into related hedging transactions, provide energy-related products and services to wholesale and retail customers, and develop, own and operate renewable and energy infrastructure projects.

Assets Held for Sale
In June 2015, Con Edison initiated a plan to sell the retail electric supply business of its competitive energy businesses (see Note U to the financial statements in Item 8).

Con Edison Transmission
Con Edison Transmission invests in electric and gas transmission projects through its wholly-owned subsidiaries, Consolidated Edison Transmission, LLC (CET Electric) and Con Edison Gas Midstream, LLC (CET Gas). CET Electric, which was formed in 2014, is investing in a company that is expected to own electric transmission assets being developed in New York. At December 31, 2015, Con Edison’s capital contribution to CET Electric was $3 million. CET Gas, which was formed in 2016, is investing in a company developing a proposed gas transmission project in West Virginia and Virginia. See “Con Edison Transmission,” below.

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. It also approves the issuance of the Utilities’ securities. See “Capital Resources,” below. It 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, it 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). O&R’s Pennsylvania subsidiary, Pike, is subject to similar regulation by the Pennsylvania Public Utility Commission (PAPUC). The NYSPSC, together with the NJBPU and the PAPUC, 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 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

14




Gas Operations – Gas Sales and Deliveries below). In 2015, 65 percent of the electricity and 31 percent of the gas CECONY delivered to its customers, and 58 percent of the electricity and 45 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 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 January 2016, the NYSPSC expanded the scope of this proceeding to include consideration of a clean energy standard and the NYSPSC staff issued a report in which it recommended that New York load serving entities be responsible for supplying a defined percentage of their retail customer load from eligible resources. The NYSPSC staff recommended that compliance be demonstrated through the use of tradable renewable energy credits and zero emissions credits or an alternative compliance payment mechanism. The NYSPSC staff suggested that utilities should act as the financial guarantor of NYSERDA’s renewable energy credit activities. In addition, the NYSPSC staff recommended that New York utilities be required to procure an appropriate percentage of their renewable energy credit targets through long-term power purchase agreements with developers of renewable generation and that utility ownership of generation be permitted only in exceptional circumstances.

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 several 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. The white paper, among other things, included proposals for: market based earnings opportunities, including distributed system platform revenues; adoption of earnings impact mechanisms to incent peak demand reduction, energy efficiency, customer engagement and information access, affordability and interconnection; retention of existing safety, reliability, customer service and utility-specific performance mechanisms; modifications to rate plan net utility plant reconciliations to encourage cost-effective use of operating resources and third-party investment; tying rate plan earnings sharing mechanisms to a performance index;

15



pre-approval, where appropriate, of investments in distributed system platform capabilities; three-year rate plans, with an opportunity for two-year extensions; and rate design and DER compensation, including net energy metering, standby service tariffs, study of demand charges and facilitation of time-of use rates. The NYSPSC is expected to make policy determinations in 2016 on the regulatory design and regulatory matters addressed in the white paper.

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, which is subject to NYSPSC review and approval, addresses AMI’s financial, operations and environmental benefits to customers and how AMI supports the REV proceeding’s objectives. AMI components include smart meters, a communication network, information technology systems and business applications. The plan provides for full deployment of AMI to the company’s customers to be implemented over a six-year period. Under the plan, aggregate estimated capital expenditures for AMI implementation would be approximately $1,300 million, including $69 million of AMI capital expenditures in 2016. O&R’s electric and gas rate plans authorize, subject to NYSPSC modification or halt following its further consideration of AMI implementation, aggregate capital expenditures of approximately $30 million to begin AMI implementation for the company’s 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.

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

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

16




the PAPUC use the rate base balances that would exist at the beginning of the rate year. 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. The tariff provisions under which RECO and Pike provide electric service provide that the company is not liable for interruptions that are due to causes beyond its control.
CECONY’s tariff for electric service also provides for reimbursement to electric customers for spoilage losses resulting from service interruptions in certain circumstances. In general, the company is obligated to reimburse affected residential and commercial customers for food spoilage of up to approximately $500 and $10,000, respectively, and reimburse affected residential customers for prescription medicine spoilage losses without limitation on amount per claim. The company’s maximum aggregate liability for such reimbursement for an incident is $15 million. The company is not required to provide reimbursement to electric customers for outages attributable to generation or transmission system facilities or events beyond its control, such as storms, provided the company makes reasonable efforts to restore service as soon as practicable.
New York electric utilities are required to provide credits to customers who are without electric service for more than three days. The credit to a customer would equal the portion of the monthly customer charge attributable to the period the customer was without service. If an extraordinary event occurs, the NYSPSC may direct New York gas utilities to implement the same policies.

The NYSPSC has approved a scorecard for use as a guide to assess electric utility performance in restoring electric service during outages that result from a major storm 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 2015, the NYSPSC approved emergency response plans submitted by CECONY and O&R, subject to certain modifications. In December 2015, 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.

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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 and the competitive energy businesses 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. 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 operates 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. 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 such as Con Edison Solutions 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 are required to have dual fuel capability. RECO, O&R’s New Jersey subsidiary, provides electric service in an area that has a different independent system operator – PJM Interconnection LLC (PJM). See “CECONY – Electric Operations – Electric Supply” and “O&R – Electric Operations – Electric Supply,” below.

Competition
The 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.

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. 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 December 31, 2015 and 2014:
Technology
CECONY
O&R
Total MW, except project number
2015
2014
2015
2014
Internal-combustion engines
103

101

25

25

Photovoltaic solar
95

58

46

28

Gas turbines
40

40



Micro turbines
10

9

1

1

Fuel cells
8

8



Steam turbines
3

3



Total distribution-level distributed generation
259

219

72

54

Number of distributed generation projects
7,451

4,200

3,709

1,953


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The competitive energy businesses participate in competitive energy supply and services businesses and renewable and energy infrastructure projects that are subject to different risks than those found in the businesses of the Utilities.
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 $16,394 million and $15,531 million at December 31, 2015 and 2014, respectively. For its transmission facilities, the costs for utility plant, net of accumulated depreciation, were $2,833 million and $2,744 million at December 31, 2015 and 2014, respectively, and for its portion of the steam-electric generation facilities, the costs for utility plant, net of accumulated depreciation, were $459 million and $451 million, at December 31, 2015 and 2014, respectively.
Distribution Facilities.     CECONY owns 62 area distribution substations and various distribution facilities located throughout New York City and Westchester County. At December 31, 2015, the company’s distribution system had a transformer capacity of 29,762 MVA, with 36,929 miles of overhead distribution lines and 97,286 miles of underground distribution lines. The underground distribution lines represent the single longest underground electric delivery system in the United States.
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, 2015, 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 potential 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 724 MW. The company expects to have sufficient amounts of gas and fuel oil available in 2016 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 energy 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:

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Year Ended December 31,
  
 
2011
 
2012
 
2013
 
2014
 
2015
Electric Energy Delivered (millions of kWh)
 
 
 
 
 
 
 
 
 
 
CECONY full service customers
 
22,622
 
20,622
 
20,118
 
19,757
 
20,206
Delivery service for retail choice customers
 
24,234
 
25,990
 
26,574
 
26,221
 
26,662
Delivery service to NYPA customers and others
 
10,408
 
10,267
 
10,226
 
10,325
 
10,147
Delivery service for municipal agencies
 
562
 
322
 

 

 

Total Deliveries in Franchise Area
 
57,826
 
57,201
 
56,918
 
56,303
 
57,015
Electric Energy Delivered ($ in millions)
 
 
 
 
 
 
 
 
 
 
CECONY full service customers
 
$5,237
 
$4,731
 
$4,799
 
$5,023
 
$4,757
Delivery service for retail choice customers
 
2,354
 
2,750
 
2,683
 
2,646
 
2,714
Delivery service to NYPA customers and others
 
555
 
596
 
602
 
625
 
600
Delivery service for municipal agencies
 
22
 
10
 

 

 

Other operating revenues
 
60
 
89
 
47
 
143
 
101
Total Deliveries in Franchise Area
 
$8,228
 
$8,176
 
$8,131
 
$8,437
 
$8,172
Average Revenue per kWh Sold (Cents) (a)
 
 
 
 
 
 
 
 
 
 
Residential
 
25.6
 
25.6
 
27.0
 
28.9
 
26.3
Commercial and Industrial
 
20.7
 
20.0
 
20.6
 
22.1
 
20.6
(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 generally occurs during the summer air conditioning season. The weather during the summer of 2015 was cooler than design conditions. CECONY’s 2015 service area peak demand was 12,316 MW, which occurred on July 20, 2015. The 2015 peak demand included an estimated 4,795 MW for CECONY’s full-service customers, 5,745 MW for customers participating in its electric retail choice program and 1,776 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 the NYISO can invoke demand reduction programs 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 2016 service area peak demand will be 13,650 MW, including an estimated 6,340 MW for its full-service customers, 5,315 MW for its electric retail choice customers and 1,995 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 2015 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 2016. 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 1,900 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, 2015, the generating stations had a combined electric capacity of approximately 724 MW, based on 2015 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

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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 plants at the Indian Point Energy Center (which is owned by Entergy Corporation subsidiaries). In February 2013, CECONY and NYPA submitted their plan, and, 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, which also address transmission congestion between upstate and downstate and make available more generation from Staten Island, are scheduled to be placed into service in 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, which are estimated to cost up to $285 million. In April 2014, the NYSPSC authorized CECONY to recover its program costs, the majority of which are expected to be incurred from 2014 through 2016, over a ten-year period through a surcharge billed to its electric delivery customers.

Gas Operations
Gas Facilities
CECONY’s capitalized costs for utility plant, net of accumulated depreciation, for gas facilities, which are primarily distribution facilities, were $5,196 million and $4,530 million at December 31, 2015 and 2014, 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 4,348 miles of mains and 369,791 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 250 MDt can be withdrawn per day. The company has about 1,226 MDt of additional natural gas storage capacity at a field in upstate New York, owned and operated by Honeoye Storage Corporation, a corporation 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:

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Year Ended December 31,
 
2011
2012
2013
2014
2015
Gas Delivered (MDt)
 
 
 
 
 
Firm Sales
 
 
 
 
 
Full service
64,696
57,595
67,007
75,630
77,197
Firm transportation of customer-owned gas
54,291
52,860
61,139
68,731
72,864
Total Firm Sales
118,987
110,455
128,146
144,361
150,061
Interruptible Sales (a)
10,035
5,961
10,900
10,498
6,332
Total Gas Delivered to CECONY Customers
129,022
116,416
139,046
154,859
156,393
Transportation of customer-owned gas
 
 
 
 
 
NYPA
34,893
48,107
48,682
47,548
44,038
Other (mainly generating plants and interruptible transportation)
97,163
108,086
87,379
105,012
104,857
Off-System Sales
97
730
4,638
15
389
Total Sales
261,175
273,339
279,745
307,434
305,677
Gas Delivered ($ in millions)
 
 
 
 
 
Firm Sales
 
 
 
 
 
Full service
$1,048
$889
$1,059
$1,141
$956
Firm transportation of customer-owned gas
356
380
414
453
458
Total Firm Sales
1,404
1,269
1,473
1,594
1,414
Interruptible Sales
74
39
69
91
46
Total Gas Delivered to CECONY Customers
1,478
1,308
1,542
1,685
1,460
Transportation of customer-owned gas
 
 
 
NYPA
2
2
2
2
2
Other (mainly generating plants and interruptible transportation)
71
68
71
70
54
Off-System Sales

5
18

1
Other operating revenues (mainly regulatory amortizations)
(30)
32
(17)
(36)
11
Total Sales
$1,521
$1,415
$1,616
$1,721
$1,528
Average Revenue per Dt Sold
 
 
 
Residential
$18.45
$18.14
$18.52
$16.76
$13.91
General
$12.96
$11.68
$12.05
$12.38
$9.73
(a)
Includes 3,801, 563, 5,362, 6,057, 1,229 MDt for 2011, 2012, 2013, 2014 and 2015, 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.
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 winter 2015/2016 (through February 1, 2016) occurred on January 4, 2016 when the demand reached 1,068 MDt. The 2015/2016 peak day demand included 551 MDt for CECONY’s full-service customers and 517 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 2016/2017 service area peak day demand will be 1,456 MDt, including an estimated 757 MDt for its full-service customers and 699 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

22




pipeline companies for the purchase of firm transportation from upstream points where gas has been purchased to the Utilities’ distribution systems, and for upstream storage services. Charges under these transportation and storage contracts are approved by the FERC. The Utilities are required to pay certain fixed charges under the supply, transportation and storage contracts whether or not the contracted capacity is actually used. These fixed charges amounted to approximately $291 million in 2015, including $252 million for CECONY. See “Contractual Obligations” below. At December 31, 2015, the contracts were for various terms extending to 2020 for supply and 2027 for the transportation and storage. In January 2016, CECONY entered into two 20-year transportation contracts, one of which is for capacity on the proposed Mountain Valley Pipeline (MVP) (see “Con Edison Transmission - CET Gas" below). In addition, the Utilities purchase gas on the spot market and contract for interruptible gas transportation. See “Recoverable Energy Costs” in Note A 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 $1,849 million and $1,795 million at December 31, 2015 and 2014, respectively.
CECONY generates steam at one steam-electric generating station and five steam-only generating stations and distributes steam to its customers through approximately 105 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,
 
2011
2012
2013
2014
2015
Steam Sold (MMlb)
 
 
 
 
 
General
519
425
547
594
538
Apartment house
5,779
5,240
6,181
6,574
6,272
Annual power
16,024
14,076
15,195
15,848
15,109
Total Steam Delivered to CECONY Customers
22,322
19,741
21,923
23,016
21,919
Steam Sold ($ in millions)
 
 
 
 
 
General
$28
$25
$31
$30
$29
Apartment house
175
158
187
180
176
Annual power
487
429
491
469
453
Other operating revenues
(7)
(16)
(26)
(51)
(29)
Total Steam Delivered to CECONY Customers
$683
$596
$683
$628
$629
Average Revenue per MMlb Sold
$30.91
$31.00
$32.34
$29.50
$30.02
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 of 2015/2016 (through February 1, 2016) occurred on January 5, 2016 when the demand reached 8.0 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 of 2016/2017 peak 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 approximately 0.8 percent.
On December 31, 2015, the steam system was capable of delivering approximately 11.3 MMlb of steam per hour, and CECONY estimates that the system will have a capacity of 11.6 MMlb of steam per hour in the 2016/2017 winter.

Steam Supply
Forty percent of the steam produced by CECONY in 2015 was supplied by the company’s steam-only generating assets; 43 percent was produced by the company’s steam-electric generating assets, where steam and electricity are primarily cogenerated; and 17 percent was purchased under an agreement with Brooklyn Navy Yard Cogeneration Partners L.P.


23



O&R
Electric Operations
Electric Facilities
O&R’s capitalized costs for utility plant, net of accumulated depreciation, for distribution facilities were $850 million and $830 million at December 31, 2015 and 2014, respectively. For its transmission facilities, the costs for utility plant, net of accumulated depreciation, was $212 million at December 31, 2015 and 2014.
O&R, RECO and Pike, own, in whole or in part, transmission and distribution facilities which include 547 circuit miles of transmission lines, 14 transmission substations, 62 distribution substations, 86,794 in-service line transformers, 3,994 pole miles of overhead distribution lines and 1,889 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 2015) 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 and Pennsylvania are not subject to a decoupling mechanism. O&R’s electric sales and deliveries for the last five years were:
 
Year Ended December 31,
 
2011
2012
2013
2014
2015
Electric Energy Delivered (millions of kWh)
 
 
 
 
 
Total deliveries to O&R full service customers
3,029
2,691
2,555
2,429
2,499
Delivery service for retail choice customers
2,760
3,040
3,166
3,240
3,237
Total Deliveries In Franchise Area
5,789
5,731
5,721
5,669
5,736
Electric Energy Delivered ($ in millions)
 
 
 
 
 
Total deliveries to O&R full service customers
$486
$405
$427
$455
$441
Delivery service for retail choice customers
157
178
192
207
213
Other operating revenues
(2)
9
9
18
9
Total Deliveries In Franchise Area
$641
$592
$628
$680
$663
Average Revenue Per kWh Sold (Cents)
 
 
 
 
 
Residential
18.0
16.7
18.1
20.3
19.2
Commercial and Industrial
13.7
13.0
14.8
16.8
15.4
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 summer air conditioning season. The weather during the summer of 2015 was cooler than design conditions. O&R’s 2015 service area peak demand was 1,405 MW, which occurred on July 20, 2015. The 2015 peak demand included an estimated 779 MW for O&R’s full-service customers and 626 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, the 2016 service area peak demand will be 1,632 MW, including an estimated 902 MW for its full-service customers and 730 MW for its electric retail choice customers. The company forecasts an average annual growth in electric peak demand in the company’s service area over the next five years at design conditions to be approximately 0.3 percent per year.

24




Electric Supply
The electricity O&R sold to its full-service customers in 2015 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 2016. 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 $502 million and $476 million at December 31, 2015 and 2014, respectively. O&R and Pike own their gas distribution systems and O&R owns a gas transmission system. 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 1,876 miles of mains and 105,482 service lines.
Gas Sales and Deliveries
O&R generally recovers the cost of the gas that it buys and then sells to its full-service customers. It does not make any margin or profit on the gas it sells. O&R’s gas revenues are subject to a weather normalization clause. O&R’s New York gas revenues (which accounted for substantially all of O&R’s gas revenues in 2015) 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,
 
2011
2012
2013
2014
2015
Gas Delivered (MDt)
 
 
 
 
 
Firm Sales
 
 
 
 
 
Full service
8,384
7,539
8,808
9,529
9,348
Firm transportation
10,823
10,505
12,062
12,592
11,752
Total Firm Sales
19,207
18,044
20,870
22,121
21,100
Interruptible Sales
4,184
4,326
4,118
4,216
4,205
Total Gas Delivered to O&R Customers
23,391
22,370
24,988
26,337
25,305
Transportation of customer-owned gas
 
 
 
 
 
Sales for resale
864
793
885
945
906
Sales to electric generating stations
24
15
19
70
25
Off-System Sales



3
62
Total Sales
24,279
23,178
25,892
27,355
26,298

25



 
Year Ended December 31,
 
2011
2012
2013
2014
2015
Gas Delivered ($ in millions)
 
 
 
 
 
Firm Sales
 
 
 
 
 
Full service
$122
$103
$115
$121
$91
Firm transportation
71
76
77
75
68
Total Firm Sales
193
179
192
196
159
Interruptible Sales
4
4
3
2
3
Total Gas Delivered to O&R Customers
197
183
195
198
162
Transportation of customer-owned gas
 
 
 
 
 
Sales to electric generating stations
1


1

Other operating revenues
16
20
10
13
20
Total Sales
$214
$203
$205
$212
$182
Average Revenue Per Dt Sold
 
 
 
 
 
Residential
$14.84
$14.01
$13.31
$13.01
$10.11
General
$13.20
$11.99
$11.53
$11.30
$8.24
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 2015/2016 (through February 1, 2016) occurred on January 4, 2016 when the demand reached 163 MDt. The 2015/2016 peak day demand included 72 MDt for O&R’s full-service customers and 91 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 2016/2017 service area peak day demand will be 224 MDt, including an estimated 99 MDt for its full-service customers and 125 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 0.6 percent in its service area.
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.
Competitive Energy Businesses
Con Edison Solutions
Con Edison Solutions primarily sells electricity to industrial, commercial and governmental customers in the northeastern United States and Texas. It also sells electricity to residential and small commercial customers (mass market) in the northeastern United States. Con Edison Solutions does not sell electricity to the Utilities. Con Edison Solutions does sell electricity to customers who are provided delivery service by the Utilities. It also provides energy efficiency services, procurement and management services to companies and governmental entities throughout most of the United States.
Con Edison Solutions was reported by DNV GL in September 2015 to be the 12th largest non-residential retail electricity provider in the United States. At December 31, 2015, it served approximately 143,000 mass market customers, excluding approximately 143,000 served under aggregation agreements. Con Edison Solutions’ electricity sales for the last five years were:
 
2011
2012
2013
2014
2015
Retail electric volumes sold (millions of kWh)
15,725
13,840
12,167
11,871
13,594
Number of retail customers accounts: (a)
 
 
 
 
 
Industrial and large commercial
42,983
35,043
35,504
35,305
42,198
Mass market
117,635
119,276
123,813
123,314
143,299
(a)
Excludes aggregation agreement customers.
Con Edison Solutions also 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

26




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 owns renewable energy projects predominately in Massachusetts and California with an aggregate capacity of 23 MW (AC).

In June 2015, Con Edison initiated a plan to sell the retail electric supply business (see Note U 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 4,465 MW of generating plants and merchant transmission in the northeastern United States owned by unrelated parties and manages energy supply assets leased from others. Among other things, the company also provides wholesale hedging and risk management services to Con Edison Solutions and Con Edison Development. The company, beginning during 2013, no longer engages in the sale of electricity to utilities. The company had sold electricity that it had purchased in wholesale markets to utilities in the northeastern United States, primarily under fixed and indexed price contracts, which they used to supply their full-service customers.

Con Edison Development
Con Edison Development develops, owns and operates energy infrastructure. The company focuses its efforts on renewable electric production projects, and at the end of 2015 was estimated to be the sixth largest owner of operating solar capacity in North America. The output of most of the projects is sold under long-term power purchase agreements (PPA). The following table provides information about the projects the company owned at December 31, 2015:
Renewable Electric Production Projects
Project Name
Production
Technology
Generating
Capacity (a)
(MW AC)
PPA Term
(In Years)
Actual/Expected
In-Service Date
Location
(State)
Wholly owned projects
 
 
 
 
 
Flemington
Solar
8
n/a (b)
2011
New Jersey
Frenchtown I, II and III
Solar
14
n/a (b)
2011-13
New Jersey
PA Solar
Solar
10
n/a (b)
2012
Pennsylvania
California Solar 2 (Partial)
Solar
60
20
2014-15
California
Oak Tree Wind
Wind
20
20
2014
South Dakota
Texas Solar 3
Solar
6
25
2015
Texas
Texas Solar 5 (c)
Solar
95
25
2015
Texas
Campbell County Wind (d)
Wind
95
30
2015
South Dakota
Projects of less than 5 MW
Solar
20
Various
Various
Various
Jointly owned projects
 
 
 
 
 
Pilesgrove
Solar
9
n/a (b)
2011
New Jersey
California Solar
Solar
55
25
2012-13
California
Mesquite Solar 1
Solar
83
20
2013
Arizona
Copper Mountain Solar 2 Phase 1 and 2
Solar
75
25
2013-2015
Nevada
Copper Mountain Solar 3
Solar
128
20
2014-2015
Nevada
Broken Bow II
Wind
38
25
2014
Nebraska
Texas Solar 4
Solar
32
25
2014
Texas
Total MW (AC) in Operation
 
748
 
 
 
California Solar 2 (Partial)
Solar
20
20
2016
California
California Solar 3 (e)
Solar
110
20
2016
California
Total MW (AC) in Construction
 
130
 
 
 
Total MW (AC), All Projects
 
878 (f)
 
 
 
(a)
Represents Con Edison Development’s ownership interest in the project.
(b)
New Jersey, Pennsylvania and Massachusetts assets have 3-5 year Solar Renewable Energy Credit hedges in place.
(c)
Purchased in May 2015. The total project cost was approximately $305 million. Electricity generated by the project is to be purchased by the City of San Antonio pursuant to a long-term power purchase agreement.
(d)
Purchased in June 2015. The total project cost was approximately $180 million. Electricity generated by the project is to be purchased by the Basin Electric Power Cooperative pursuant to a long-term power purchase agreement.

27



(e)
Purchased in January and February 2015. The total project cost is expected to be approximately $300 million. Electricity generated by these projects is to be purchased by Pacific Gas and Electric Company and Southern California Edison pursuant to long-term power purchase agreements.
(f)
In addition, in September 2015, Con Edison Development purchased a 50 percent membership interest in Panoche Holdings, LLC, which owns a project company that is developing, but has not started constructing, a 247 MW (AC) solar electric production project in California. See Note Q to the financial statements in Item 8. See “Capital Requirements,” below. Also, in October 2015, Con Edison Development purchased Lost Hills, which is developing but has not started constructing, a 20 MW (AC) solar electric production project in California and in November 2015 purchased Upton County, which is developing but has not started constructing, a 150 MW (AC) solar electric production project in Texas.
In January 2016, Con Edison Development purchased a company that is the owner of a106 MW (AC) solar electric production project in Texas (Texas Solar 7). The total cost of this project is expected to be approximately $375 million. The project will be 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.

Con Edison Transmission
CET Electric
In January 2016, Con Edison transferred a wholly-owned subsidiary, Consolidated Edison Transmission LLC (CET Electric), to another wholly-owned subsidiary, Con Edison Transmission, Inc. (Con Edison Transmission). In November 2014, CET Electric, along with affiliates of certain other New York transmission owners, formed New York Transco LLC (NY Transco). CET Electric owns a 45.7 percent interest in NY Transco. NY Transco’s transmission projects are expected to be developed initially by CECONY and other New York transmission owners and, subject to NYSPSC approval, sold to NY Transco.
Initially, NY Transco projects are expected to include three projects (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, which are scheduled to be placed into service by Summer 2016, include two projects that CECONY is developing and one project that another regulated affiliate of NY Transco is developing. The current aggregated estimated cost of the TOTS projects is approximately $230 million (most of which is for the projects CECONY is developing).
In April 2015, FERC issued an order granting certain transmission incentives for NY Transco projects. In November 2015, NY Transco, certain New York transmission owners (including CECONY and O&R), the NYSPSC and other parties submitted to FERC for approval a settlement agreement applicable to the TOTS Projects (other than costs that have not already been incurred related to a portion of one of the projects that may no longer be needed). The settlement agreement, among other things, provides for a 10 percent return on common equity (or 9.5 percent for capital costs in excess of $228 million incurred prior to the projects’ commercial operation date), a maximum common equity ratio of 53 percent and allocation of 63 percent of the costs of the projects 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 New York transmission owners other than CECONY until the project was sold to NY Transco. The NYSPSC also directed certain developers, including NY Transco, to submit project(s) to the NYISO. Under its public policy planning process, the NYISO will solicit and evaluate proposed project(s) that meet the public policy need and make a selection in accordance with its FERC-approved criteria. The cost of the project(s) selected by the NYISO would be recoverable through the NYISO’s tariff.

CET Gas
In January 2016, Con Edison Transmission formed Con Edison Gas Midstream, LLC (CET Gas) and CET Gas acquired a 12.5 percent ownership interest in MVP, a company developing a proposed gas transmission project in West Virginia and Virginia. MVP has indicated that the estimated total project cost is $3,000 million to $3,500 million, and that, subject to FERC approval, MVP is targeting to be fully in-service during the fourth quarter of 2018.

Capital Requirements and Resources
Capital Requirements
The following table contains the Companies’ capital requirements for the years 2013 through 2015 and their current estimate of amounts for 2016 through 2018:

28




  
Actual
Estimate
(Millions of Dollars)
2013
2014
2015
2016
2017
2018
Regulated utility construction expenditures
 
 
 
 
 
 
CECONY (a)(b)
 
 
 
 
 
 
Electric
$1,471
$1,500
$1,658
$1,978
$2,002
$1,975
Gas
536
549
671
790
928
944
Steam
128
83
106
97
69
72
Sub-total
2,135
2,132
2,435
2,865
2,999
2,991
O&R
 
 
 
 
 
 
Electric
98
105
114
140
137
134
Gas
37
37
46
48
48
50
Sub-total
135
142
160
188
185
184
Total regulated utility construction expenditures
2,270
2,274
2,595
3,053
3,184
3,175
Con Edison Transmission
 
 
 
 
 
 
CET Electric



58


CET Gas



57
171
179
Sub-total



115
171
179
Competitive energy businesses capital expenditures
 
 
 
 
 
 
Renewable and energy infrastructure projects
378
447
823
985
360
360
Sub-total
378
447
823
985
360
360
Total capital expenditures
2,648
2,721
3,418
4,153
3,715
3,714
Retirement of long-term securities
 
 
 
 
 
 
Con Edison – parent company
2
2
2
2
2
2
CECONY
700
475
350
650

1,200
O&R
3
3
143
79
4
54
Competitive energy businesses
1
5
4

8
10
10
Total retirement of long-term securities
706
485
499
739
16
1,266
Total capital requirements
$3,354
$3,206
$3,917
$4,892
$3,731
$4,980
(a)
CECONY’s capital expenditures for environmental protection facilities and related studies were $178 million, $218 million and $224 million in 2013, 2014 and 2015, respectively, and are estimated to be $246 million in 2016.
(b)
Estimates do not include amounts for the energy efficiency, demand reduction and combined heat and power programs discussed under “CECONY – Electric Operations – Electric Supply,” above.

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 new clean energy technologies into the Utilities’ electric delivery systems and accelerate their gas main replacement program.

Estimated capital expenditures for Con Edison Transmission reflect planned investments in electric and gas transmission projects. Estimated capital expenditures for the competitive energy businesses reflect planned investments in renewable generation and energy infrastructure projects. Actual capital expenditures for Con Edison Transmission and the competitive energy businesses could significantly increase or decrease from the amounts estimated depending on market conditions and opportunities.

Contractual Obligations
The following table summarizes the Companies’ material obligations at December 31, 2015 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.

29



  
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
$11,536
$650
$1,200
$825
$8,861
O&R
675
79
58
63
475
Competitive energy businesses and parent
647
10
24
29
584
Interest on long-term debt (a)
10,842
602
1,147
946
8,147
Total long-term debt, including interest
23,700
1,341
2,429
1,863
18,067
Capital lease obligations (Note J)
 
 
 
 
 
CECONY
3
1
1
1

Total capital lease obligations
3
1
1
1

Operating leases (Notes J and Q)
 
 
 
 
 
CECONY
98
12
24
19
43
O&R
4
1
1
1
1
Competitive energy businesses
106
5
11
11
79
Total operating leases
208
18
36
31
123
Purchase obligations
 
 
 
 
 
Electricity purchase power agreements – Utilities (Note I)
 
 
 
 
 
CECONY
 
 
 
 
 
Energy (b)
3,634
577
554
347
2,156
Capacity
1,235
180
187
105
763
Total CECONY
4,869
757
741
452
2,919
O&R
 
 
 
 
 
Energy and Capacity (b)
118
76
42


Total electricity and purchase power agreements – Utilities
4,987
833
783
452
2,919
Natural gas supply, transportation, and storage contracts – Utilities (c)
 
 
 
 
CECONY
 
 
 
 
 
Natural gas supply
206
108
79
19

Transportation and storage
1,063
236
403
148
276
Total CECONY
1,269
344
482
167
276
O&R
 
 
 
 
 
Natural gas supply
17
6
7
4

Transportation and storage
198
44
75
28
51
Total O&R
215
50
82
32
51
Total natural gas supply, transportation and storage contracts
1,484
394
564
199
327
Other purchase obligations
 
 
 
 
 
CECONY (d)
3,869
1,577
1,629
641
22
O&R (d)
237
91
127
5
14
Competitive energy businesses (e)
384
324
56
4

Total other purchase obligations
4,490
1,992
1,812
650
36
Uncertain tax positions (f)
12
12



Total
$34,884
$4,591
$5,625
$3,196
$21,472
(a)
Includes interest on variable rate debt calculated at rates in effect at December 31, 2015.
(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 Con Edison’s competitive energy businesses.
(f)
Con Edison reasonably expects to resolve approximately $25 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

30




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 its competitive 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 Utilities finance their operations, capital requirements and payment of dividends to Con Edison from internally-generated funds, contributions of equity capital from Con Edison, if any, and external borrowings. See "Liquidity and Capital Resources" in Item 7.
Con Edison plans to meet its 2016 capital requirements, including for maturing securities, through internally-generated funds and the issuance of securities. The company’s plans include the issuance of between $1,000 million and $1,500 million of long-term debt 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 $200 million of common equity in addition to equity under its dividend reinvestment, employee stock purchase and long term incentive plans.

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.

In 2012, the NYSPSC authorized CECONY, through 2016, to issue up to $3,500 million of debt securities ($3,200 million of which the company had issued as of December 31, 2015). In 2013, the NYSPSC authorized O&R, through 2017, to issue up to $305 million of debt securities ($220 of which the company had issued as of December 31, 2015). 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, 2015, the Utilities had not refunded any securities pursuant to this authorization. In January 2016, CECONY filed a petition with the NYSPSC for authorization to issue up to $5,200 million of debt securities prior to December 31, 2019.
Con Edison’s competitive 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
 
2011
2012
2013
 
2014
2015
Con Edison
3.6

3.7

3.0

(a) 
3.6

3.5

CECONY
3.8

3.7

3.7

  
3.8

3.6

(a)
Reflects $95 million after-tax charge to earnings relating to Con Edison Development’s LILO transactions. See Note J to the financial statements in Item 8.

31



For each of the Companies, the common equity ratio for the last five years was:
 
Common Equity Ratio
(Percent of total capitalization)
 
2011
2012
2013
2014
2015
Con Edison
53.6
54.3
54.0
52.2
52.1
CECONY
53.3
53.7
53.8
50.9
51.4
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. Con Edison’s issuer credit rating is A3, A- 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 0.14 percent on December 31, 2015. The weighted average interest rate was 0.14 percent, 0.10 percent and 0.17 percent for the years 2015, 2014 and 2013, 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 (2014) 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))
2011
2012
2013
2014
2015
CO2 equivalent emissions
3.4

3.3

3.4

3.2

3.1

(a)
Estimated emissions for 2015 are subject to third-party verification.
Con Edison’s 48 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 for leak repair prioritization and to reduce work-related losses. 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. The Utilities 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 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 energy efficiency programs from their customers primarily through NYSPSC-approved energy efficiency tracker surcharge mechanisms.
Through the Utilities’ energy-efficiency programs, customers reduced their annual energy use by approximately 1,005,000 MWh of electricity and 1,395,000 Dt of gas from the programs’ inception in 2009 through 2015, resulting in their avoiding their release of approximately 650,000 tons of GHG into the atmosphere every year. In addition, CECONY’s other demand-side management programs assisted customers in reducing their annual energy use by approximately 281,000 MWh of electricity from the programs’ inception in 2004 through 2015, resulting in their avoiding their release of approximately 158,000 tons of GHG into the atmosphere every year.
Emissions are also avoided by renewable electric production facilities replacing fossil-fueled electric production facilities. NYSERDA is responsible for implementing the renewable portfolio standard (RPS) established by the NYSPSC. NYSERDA enters 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 provides rebates to customers who install eligible renewable electric production technologies. The electricity produced by such customer-sited renewables 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 $131 million and $121 million in 2015 and 2014, respectively, (and approximately $678 million cumulatively from 2006) to fund these NYSERDA programs. In March 2015, NYSERDA reported that the statewide environmental benefits of having electricity generated by renewable production facilities from 2006 through 2014, 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. 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. 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 January 2016, the NYSPSC approved a 10-year $5.3 billion clean energy fund to be managed by NYSERDA under the direction of the NYSPSC. The clean energy fund has four porfolios: market development; innovation and research; NY Green Bank and NY Sun. The Utilities will eliminate the separate RPS tariff and 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).
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, such as the Regional Greenhouse Gas Initiative (RGGI), and renewable energy and energy efficiency programs. State plans are to be submitted to the EPA in 2016, with possible extensions to 2018, and are to be in effect not later than 2022. The costs resulting from the Clean Power Plan could be substantial. 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

33



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 $484 million to $2,280 million.
Astoria Site
CECONY is permitted by the NYSDEC to operate a hazardous waste storage facility on property owned by it in the Astoria section of Queens, New York. Portions of the property were formerly the location of a manufactured gas plant and also have been used or are being used for, among other things, electric generation operations, electric substation operations, the storage of fuel oil and liquefied natural gas, and the maintenance and storage of electric equipment. As a condition of its NYSDEC permit, the company is required to investigate the property and, where environmental contamination is found and action is necessary, to remediate the contamination. The company’s investigations are ongoing. The company has submitted 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 range from $158 million to $461 million.


34




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 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 EPA estimates will cost $35 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 October 2015, CECONY received a notice of violation from the NYSDEC relating to a September 2015 discharge of dielectric fluid from an electric transmission line into the Bronx River. This administrative proceeding may result in monetary sanctions of more than $0.1 million for violations of certain New York State provisions regulating the discharge of materials into, and for the protection of, the environment. Remediation has been substantially completed at a cost of $1.4 million. CECONY is continuing to monitor the site. 
CECONY is a PRP at additional Superfund sites involving other PRPs and participates in PRP groups at those sites. The company generally is not managing the site investigation and remediation at these multiparty sites. Work at these sites is in various stages, and investigation, remediation and monitoring activities at some of these sites can be expected to continue over extended periods of time. The company believes that it is unlikely that monetary sanctions, such as penalties, will be imposed by any governmental authority with respect to these sites.
The following table lists each of the additional Superfund sites for which the company anticipates it may have liability. The table also shows for each such site its location, the year in which the company was designated or alleged to be a PRP or to otherwise have responsibilities for the site (shown in the table under “Start”), the name of the court or agency in which proceedings for the site are pending and CECONY’s estimated percentage of the total liability for each site. The company currently estimates that its potential liability for investigation, remediation, monitoring and environmental damages at each site is $0.2 million or less, with the exception of the Cortese Landfill site for which the estimate is $0.9 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.

35



Site
Location
Start
Court or
Agency
% of Total
Liability
Maxey Flats Nuclear
Morehead, KY
1986
EPA
0.8%
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. Remedial design is ongoing for the remaining three 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 $100 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 at each site is less than $0.3 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%
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.

36




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 2015 and expects to comply with the rule in 2016. 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
Con Edison has no employees other than those of CECONY, O&R and Con Edison’s competitive energy businesses (which at December 31, 2015 had 13,393, 1,131 and 282 employees, respectively). Of the CECONY and O&R employees, 8,202 and 615 employees, respectively, were represented by a collective bargaining unit. The collective bargaining agreement covering most of these CECONY employees expires in June 2016. 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.
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:

37



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 competitive 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 the Companies. 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. In January 2016, CECONY submitted requests to the NYSPSC for new rate plans for electric and gas delivery service to take effect in January 2017. 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 and “Other Regulatory Matters” in Note B to the financial statements in Item 8.
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” in Item 1.

38




A Cyber Attack Could Adversely Affect the Companies.    The Utilities and other operators of critical energy infrastructure may face a heightened risk of cyber attack. 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. Con Edison’s competitive energy businesses also depend on wholesale energy markets to supply electricity to their customers. See “Competitive Energy Businesses” in Item 1. A disruption in the wholesale energy markets or a failure on the part of the Companies’ energy suppliers or operators of energy delivery systems that connect to the Utilities’ energy facilities could adversely affect the Companies’ 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.
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 competitive energy businesses 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.
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, regulation, tax policy, customer behavior or technology could significantly impact the value of the Utilities’ energy delivery facilities, the competitive energy businesses’ renewable and energy infrastructure projects and Con Edison Transmission's investment in electric and gas transmission projects. Such changes could

39



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 and the competitive energy businesses.
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).
Competitive Energy Businesses
For a discussion of the competitive energy businesses’ facilities, see “Competitive Energy Businesses” 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 Explosion” 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 18, 2016. 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.

40




Name
Age
Offices and Positions During Past Five Years
Executive Officers of Con Edison and CECONY
John McAvoy
55
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
53
12/09 to present – President of CECONY
Robert Hoglund
54
9/05 to present – Senior Vice President and Chief Financial Officer of Con Edison and CECONY
Elizabeth D. Moore
61
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
Joseph P. Oates
54
1/16 to present – President of Con Edison Transmission
 
 
9/15 to present – 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
Frances A. Resheske
55
2/02 to present – Senior Vice President – Public Affairs of CECONY
Saumil P. Shukla
56
9/15 to present – Senior Vice President – Utility Shared Services of CECONY
 
 
10/14 to 8/15 – Vice President – Supply Chain of CECONY
Robert Muccilo
59
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
50
1/08 to present – Vice President of Strategic Planning of CECONY
Scott Sanders
52
2/10 to present – Vice President and Treasurer of Con Edison and CECONY
 
 
 
Executive Officers of Con Edison but not CECONY
Timothy P. Cawley
51
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
 
 
9/07 to 4/11 – Vice President – Bronx and Westchester Electric Operations of CECONY
 
 
 
Executive Officers of CECONY but not Con Edison
(All offices and positions listed are with CECONY)
Milovan Blair
53
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
 
 
2/09 to 4/11 – Vice President – System and Transmission Operations
Marilyn Caselli
61
5/05 to present – Senior Vice President – Customer Operations
Marc E. Huestis
55
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 2/13 – Vice President – Construction
Robert D. Schimmenti
51
9/14 to present – Senior Vice President – Electric Operations
 
 
5/10 to 8/14 – Vice President – Engineering and Planning


41



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 29, 2016, there were 48,735 holders of record of Con Edison’s Common Shares.
The market price range for Con Edison’s Common Shares during 2015 and 2014, as reported in the consolidated reporting system, and the dividends paid by Con Edison in 2015 and 2014 were as follows:

2015
2014

High
Low
Dividends
Paid
High
Low
Dividends
Paid
1st Quarter
$72.25
$58.65
$0.65
$56.68
$52.23
$0.63
2nd Quarter
$63.03
$56.86
$0.65
$58.57
$52.87
$0.63
3rd Quarter
$67.37
$57.71
$0.65
$58.12
$54.58
$0.63
4th Quarter
$67.94
$60.30
$0.65
$68.92
$56.40
$0.63
On January 21, 2016, Con Edison declared a quarterly dividend of 67 cents per Common Share. The first quarter 2016 dividend will be paid on March 15, 2016.
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 2015, the market price of Con Edison’s Common Shares decreased by 2.64 percent (from $66.01 at year-end 2014 to $64.27 at year-end 2015). By comparison, the S&P 500 Index decreased 0.7 percent and the S&P 500 Utilities Index decreased 8.4 percent. The total return to Con Edison’s common shareholders during 2015, including both price appreciation and investment of dividends, was 1.4 percent. By comparison, the total returns for the S&P 500 Index and the S&P 500 Utilities Index were 1.4 percent and -4.8 percent, respectively. For the five-year period 2011 through 2015 inclusive, Con Edison’s shareholders’ total return was 60.3 percent, compared with total returns for the S&P 500 Index and the S&P 500 Utilities Index of 80.8 percent and 68.8 percent, respectively.


42




 
Years Ended December 31,
Company / Index
2010
2011
2012
2013
2014
2015
Consolidated Edison, Inc.
100.00
130.82
122.02
126.65
158.05
160.28
S&P 500 Index
100.00
102.11
118.45
156.82
178.28
180.75
S&P Utilities
100.00
119.91
121.46
137.51
177.36
168.77
Based on $100 invested at December 31, 2010, 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 2014 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 also owns competitive energy businesses and Con Edison Transmission. See “The Utilities,” “Competitive 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, 2015
At December 31, 2015
(Millions of Dollars,
except percentages)
Operating
Revenues
Net
Income
Assets
CECONY
$10,328
82
%
$1,084
91
%
$40,230
88
%
O&R (a)
845
7
%
52
4
%
2,719
6
%
Total Utilities
11,173
89
%
1,136
95
%
42,949
94
%
Competitive energy businesses (b)
1,383
11
%
59
5
%
1,680
4
%
Other (c)
(2)
%
(2)
%
1,013
2
%
Total Con Edison
$12,554
100
%
$1,193
100
%
$45,642
100
%
(a)
Net income for the year ended December 31, 2015 includes $3 million related to the impairment of Pike assets held for sale. Assets at December 31, 2015 include assets classified as held for sale of $23 million. See Note U to the financial statements in Item 8.
(b)
Operating revenues and net income from the competitive energy businesses for the year ended December 31, 2015 includes $1,174 million and $27 million respectively, related to their electric supply business. Assets at December 31, 2015 include assets classified as held for sale of $134 million (see Note U to the financial statements in Item 8).
(c)
Other includes parent company, consolidation adjustments and Con Edison Transmission.
Results of Operations
Net income and earnings per share for the years ended December 31, 2015, 2014 and 2013 were as follows:
(Millions of Dollars,
except per share amounts)
Net Income
Earnings per Share
  
2015
2014
2013
2015
2014
2013
CECONY
$1,084
$1,058
$1,020

$3.70


$3.61


$3.48

O&R (a)
52
60
65
0.18

0.20

0.22

Competitive energy businesses (b)(c)
59
(17)
(23)
0.20

(0.05
)
(0.08
)
Other (d)
(2)
(9)

(0.01
)
(0.03
)

Con Edison (e)
$1,193
$1,092
$1,062

$4.07


$3.73


$3.62

(a)
Includes $3 million or $0.01 a share of net loss in 2015 related to the impairment of Pike assets held for sale (see Note U to the financial statements in Item 8).
(b)
Includes $(73) million or $(0.25) a share and $45 million or $0.14 a share of net after-tax mark-to-market (losses)/gains in 2014 and 2013, respectively. Also includes an after-tax gain on sale of solar electric production projects of $26 million (see Note Q to the financial statements in Item 8) in 2014. Includes an after-tax charge of $1 million and $95 million or $0.32 a share relating to the LILO transactions (see “Lease In/Lease Out Transactions” in Note J to the financial statements in Item 8) in 2014 and 2013, respectively. Also includes a tax benefit of $15 million or $0.05 a share resulting from the acceptance by the Internal Revenue Service (IRS) of the company’s claim for manufacturing tax deductions in 2013.
(c)
Includes $27 million or $0.09 a share, $(75) million or $(0.26) a share and $45 million or $0.14 a share of net income/(loss) in 2015, 2014 and 2013, respectively, related to the retail electric supply business. See Note U to the financial statements in Item 8. These amounts reflect net after-tax mark-to-market gains/(losses) of $(1) million, $(76) million or $(0.26) a share and $45 million or $0.14 a share in 2015, 2014 and 2013, respectively.
(d)
Other includes parent company and consolidation adjustments.
(e)
Earnings per share on a diluted basis were $4.05 a share, $3.71 a share and $3.61 a share in 2015, 2014 and 2013, respectively.
The Companies’ results of operations for 2015, as compared with 2014, and for 2014, as compared with 2013, primarily reflect the performance of the rate plans of Con Edison's utility subsidiaries, growth in gas delivery service related to oil-to-gas conversions and the weather impact on its steam delivery service. The rate plans provide for revenues to cover expected increases in certain operating costs including depreciation and property taxes. In

44




addition, the results of operations reflect higher profits from the competitive energy businesses' retail electric supply business. The results of operations also include the impairment of Pike assets held for sale, the gain on sale of solar electric production projects, the impact of LILO transactions and the net mark-to-market effects of the competitive energy businesses.
The following table presents the estimated effect on earnings per share and net income for 2015 as compared with 2014, and 2014 as compared with 2013, resulting from these and other major factors:
  
2015 vs. 2014 Variation
2014 vs. 2013 Variation
(Millions of Dollars,
except per share amounts)
Earnings per
Share
Net
Income
Earnings per
Share
Net
Income
CECONY (a)
 
 
 
 
     Changes in rate plans
$0.51
$147
$0.43
$125
     Weather impact on steam revenues
(0.04)
(13)
0.03
10
     Other operations and maintenance expenses
(0.02)
(5)
(0.28)
(83)
     Depreciation and property taxes
(0.22)
(64)
(0.09)
(26)
     Net interest expense
(0.10)
(28)
(0.03)
(10)
     Other (b)
(0.04)
(11)
0.07
22
Total CECONY
0.09
26
0.13
38
O&R (a)
 
 
 
 
     Changes in rate plans
0.04
13
0.04
11
     Other operations and maintenance expenses
(0.03)
(9)
(0.03)
(10)
     Other (c)
(0.03)
(12)
(0.03)
(6)
Total O&R
(0.02)
(8)
(0.02)
(5)
Competitive energy businesses
 
 
 
 
     Operating revenues less energy costs
0.39
115
(0.34)
(100)
     Gain on sale of solar electric production projects
(0.09)
(26)


     Other operations and maintenance expenses
(0.06)
(16)
(0.01)
(2)
     Net interest expense
(0.04)
(11)
0.29
86
     Other
0.05
14
0.09
22
Total competitive energy businesses (d)
0.25
76
0.03
6
Other, including parent company expenses (e)
0.02
7
(0.03)
(9)
Total variations
$0.34
$101
$0.11
$30
(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)
These 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, for the year ended December 31, 2014.
(c)
These variations include the impairment of Pike assets held for sale in 2015 shown in note (a) in the Results of Operations table above.
(d)
These variations include the net mark-to-market effects, the gain on sale of solar electric production projects, the impact of the LILO transactions and the manufacturing tax deduction shown in note (b) in the Results of Operations table above.
(e)
These variations reflect certain income tax benefits for Con Edison (parent company) of $7 million or $0.02 a share and $16 million or $0.06 a share for the years ended December 31, 2015 and December 31, 2013, respectively.

The Companies’ other operations and maintenance expenses for the years ended December 31, 2015, 2014 and 2013 were as follows:

45



(Millions of Dollars)
2015
2014
2013
CECONY
 
 
 
Operations
$1,464
$1,384
$1,313
Pensions and other postretirement benefits
364
467
485
Health care and other benefits
159
149
133
Regulatory fees and assessments (a)
550
519
505
Other
344
354
299
Total CECONY
2,881
2,873
2,735
O&R
333
318
302
Competitive energy businesses
134
108
105
Other (b)
(4)
(5)
(5)
Total other operations and maintenance expenses
$3,344
$3,294
$3,137
(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 and Con Edison’s competitive energy businesses. 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, 2015, 2014 and 2013 follows. For additional business segment financial information, see Note N to the financial statements in Item 8.
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
Competitive Energy
Businesses
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
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)
Includes parent company and consolidation adjustments.
(b)
Represents the consolidated results of operations of Con Edison and its businesses.

46




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).

47



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).
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.


48




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).
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).

49



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.
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)

50




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
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 and Pennsylvania 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:

51



  
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)
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.


52




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.
Competitive Energy Businesses
The competitive 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 maintenance 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. See “Lease In/Lease Out Transactions” in Note J to the financial statements in Item 8.

53



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.
Year Ended December 31, 2014 Compared with Year Ended December 31, 2013
The Companies’ results of operations in 2014 compared with 2013 were:
 
CECONY
O&R
Competitive Energy
Businesses
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
Operating revenues
$356
3.4
%
$59
7.1
%
$148
13.5
%
$2
40.0
%
$565
4.6
%
Purchased power
70
3.5

21
9.7

227
26.4



318
10.3

Fuel
(35)
(10.9
)






(35)
(10.9
)
Gas purchased for resale
77
14.5

12
15.8

88
Large

(1)
Large

176
27.7

Other operations and maintenance
138
5.0

16
5.3

3
2.9



157
5.0

Depreciation and amortization
45
4.8

5
8.9

(4)
(17.4
)
1
Large

47
4.6

Taxes, other than income taxes
(18)
(1.0
)
(2)
(3.2
)
2
11.8



(18)
(0.9
)
Gain on sale of solar electric production projects




45



45

Operating income (loss)
79
3.8

7
5.8

(123)
Large

2
Large

(35)
(1.6
)
Other income less deductions
10
Large

2
Large

20
Large

(3)
Large

29
Large

Net interest expense
16
3.1

(2)
(5.4
)
(143)
Large

1
3.8

(128)
(17.8
)
Income before income tax expense
73
4.7

11
13.1

40
62.5

(2)
(9.1
)
122
7.9

Income tax expense
35
6.7

16
84.2

34
82.9

7
31.8

92
19.3

Net income
$38
3.7
%
$(5)
(7.7
)%
$6
26.1
%
$(9)
Large

$30
2.8
%
(a)
Includes parent company and consolidation adjustments.
(b)
Represents the consolidated results of operations of Con Edison and its businesses.

54




CECONY
  
For the Year Ended
December 31, 2014
  
For the Year Ended
December 31, 2013
  
  
(Millions of Dollars)
Electric
Gas
Steam
2014
Total
Electric
Gas
Steam
2013
Total
2014-2013
Variation
Operating revenues
$8,437
$1,721
$628
$10,786
$8,131
$1,616
$683
$10,430
$356
Purchased power
2,036

55
2,091
1,974

47
2,021
70
Fuel
180

105
285
174

146
320
(35)
Gas purchased for resale

609

609

532

532
77
Other operations and maintenance
2,270
418
185
2,873
2,180
351
204
2,735
138
Depreciation and amortization
781
132
78
991
749
130
67
946
45
Taxes, other than income taxes
1,458
248
92
1,798
1,459
241
116
1,816
(18)
Operating income
$1,712
$314
$113
$2,139
$1,595
$362
$103
$2,060
$79
Electric
CECONY’s results of electric operations for the year ended December 31, 2014 compared with the year ended December 31, 2013 is as follows:
  
For the Years Ended December 31,
  
(Millions of Dollars)
2014
2013
Variation
Operating revenues
$8,437
$8,131
$306
Purchased power
2,036
1,974
62
Fuel
180
174
6
Other operations and maintenance
2,270
2,180
90
Depreciation and amortization
781
749
32
Taxes, other than income taxes
1,458
1,459
(1)
Electric operating income
$1,712
$1,595
$117
CECONY’s electric sales and deliveries in 2014 compared with 2013 were:
  
Millions of kWh Delivered
 
Revenues in Millions (a)
  
For the Years Ended
  
 
For the Years Ended
  
Description
December 31, 2014
December 31, 2013
Variation
Percent
Variation
 
December 31, 2014
December 31, 2013
Variation
Percent
Variation
Residential/Religious (b)
9,868

10,273

(405
)
(3.9
)%
 
$2,847
$2,773
$74
2.7
%
Commercial/Industrial
9,834

9,776

58

0.6

 
2,176
2,013
163
8.1

Retail choice customers
26,221

26,574

(353
)
(1.3
)
 
2,646
2,683
(37)
(1.4
)
NYPA, Municipal Agency and other sales
10,380

10,295

85

0.8

 
625
615
10
1.6

Other operating revenues (c)




 
143
47
96
Large

Total
56,303

56,918

(615
)
(1.1
)%
(d)
$8,437
$8,131
$306
3.8
%
(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 decreased 0.1 percent in 2014 compared with 2013.
Operating revenues increased $306 million in 2014 compared with 2013 due primarily to higher revenues from the electric rate plan ($215 million), higher purchased power ($62 million) and fuel expenses ($6 million).
Purchased power expenses increased $62 million in 2014 compared with 2013 due to an increase in unit costs ($56 million) and purchased volumes ($6 million).
Fuel expenses increased $6 million in 2014 compared with 2013 due to higher unit costs ($34 million), offset by lower sendout volumes from the company’s electric generating facilities ($28 million).

55



Other operations and maintenance expenses increased $90 million due primarily to higher costs for the support and protection of company underground facilities to accommodate New York City municipal projects ($25 million), higher costs for injuries and damages ($24 million), an increase in healthcare costs ($12 million) and an increase in the surcharges for assessments and fees that are collected in revenues from customers ($11 million).
Depreciation and amortization increased $32 million due primarily to higher electric utility plant balances.
Taxes, other than income taxes decreased $1 million principally due to a sales and use tax refund, offset in part by higher property taxes.
Gas
CECONY’s results of gas operations for the year ended December 31, 2014 compared with the year ended December 31, 2013 is as follows:
  
For the Years Ended December 31,
  
(Millions of Dollars)
2014
2013
Variation
Operating revenues
$1,721
$1,616
$105
Gas purchased for resale
609
532
77
Other operations and maintenance
418
351
67
Depreciation and amortization
132
130
2
Taxes, other than income taxes
248
241
7
Gas operating income
$314
$362
$(48)
CECONY’s gas sales and deliveries, excluding off-system sales, in 2014 compared with 2013 were:
  
Thousands of Dt Delivered
 
Revenues in Millions (a)
  
For the Years Ended
  
 
For the Years Ended
  
Description
December 31, 2014
December 31, 2013
Variation
Percent
Variation
 
December 31, 2014
December 31, 2013
Variation
Percent
Variation
Residential
46,661

38,872

7,789

20.0
%
 
$782
$720
$62
8.6
%
General
28,969

28,135

834

3.0

 
359
339
20
5.9

Firm transportation
68,731

61,139

7,592

12.4

 
453
414
39
9.4

Total firm sales and transportation
144,361

128,146

16,215

12.7

(b) 
1,594
1,473
121
8.2

Interruptible sales (c)
10,498

10,900

(402
)
(3.7
)
 
91
69
22
31.9

NYPA
47,548

48,682

(1,134
)
(2.3
)
 
2
2


Generation plants
82,146

62,764

19,382

30.9

 
30
26
4
15.4

Other
22,866

24,615

(1,749
)
(7.1
)
 
40
45
(5)
(11.1
)
Other operating revenues (d)




 
(36)
1
(37)
Large

Total
307,419

275,107

32,312

11.7
%
 
$1,721
$1,616
$105
6.5
%
(a)
Revenues from gas sales are subject to a weather normalization clause and a revenue decoupling mechanism, as a result of which, delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.
(b)
After adjusting for variations, principally weather and billing days, firm gas sales and transportation volumes in the company’s service area increased 8.0 percent in 2014 compared with 2013, reflecting primarily higher oil-to-gas conversions and transfers to firm service.
(c)
Includes 6,057 and 5,362 thousands of Dt for 2014 and 2013, 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 increased $105 million in 2014 compared with 2013 due primarily to an increase in gas purchased for resale expenses ($77 million) and higher revenues from the gas rate plan ($31 million).
Gas purchased for resale increased $77 million in 2014 compared with 2013 due to higher unit costs ($67 million) and sendout volumes ($10 million).
Other operations and maintenance expenses increased $67 million due primarily to higher operating costs attributable to emergency response ($25 million), higher pension costs ($10 million), an increase in the surcharges for assessments and fees that are collected in revenues from customers ($8 million), higher costs for injuries and damages ($4 million) and higher healthcare costs ($2 million).
Depreciation and amortization increased $2 million due primarily to higher gas utility plant balances.

56




Taxes, other than income taxes increased $7 million principally due to higher state and local revenue taxes and property taxes, offset in part by a sales and use tax refund.
Steam
CECONY’s results of steam operations for the year ended December 31, 2014 compared with the year ended December 31, 2013 is as follows:
  
For the Years Ended December 31,
  
(Millions of Dollars)
2014
2013
Variation
Operating revenues
$628
$683
$(55)
Purchased power
55
47
8
Fuel
105
146
(41)
Other operations and maintenance
185
204
(19)
Depreciation and amortization
78
67
11
Taxes, other than income taxes
92
116
(24)
Steam operating income
$113
$103
$10
CECONY’s steam sales and deliveries in 2014 compared with 2013 were:
  
Millions of Pounds Delivered
 
Revenues in Millions
  
For the Years Ended
  
 
For the Years Ended
  
Description
December 31, 2014
December 31, 2013
Variation
Percent
Variation
 
December 31, 2014
December 31, 2013
Variation
Percent
Variation
General
594

547

47

8.6
%
 
$30
$31
$(1)
(3.2
)%
Apartment house
6,574

6,181

393

6.4

 
180
187
(7)
(3.7
)
Annual power
15,848

15,195

653

4.3

 
469
491
(22)
(4.5
)
Other operating revenues (a)




 
(51)
(26)
(25)
96.2

Total
23,016

21,923

1,093

5.0
%
(b) 
$628
$683
$(55)
(8.0
)%
(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 increased 1.8 percent in 2014 compared with 2013, reflecting higher average normalized use per customer.
Operating revenues decreased $55 million in 2014 compared with 2013 due primarily to lower fuel expenses ($41 million) and lower revenues from the steam rate plans ($38 million), offset in part by the weather impact on revenues ($17 million) and higher purchased power costs ($8 million).
Purchased power expenses increased $8 million in 2014 compared with 2013 due to an increase in unit costs ($7 million) and purchased volumes ($1 million).
Fuel expenses decreased $41 million in 2014 compared with 2013 due to lower unit costs ($44 million), offset by higher sendout volumes ($3 million).
Other operations and maintenance expenses decreased $19 million due primarily to the absence in 2014 of certain previously deferred pension costs that were recognized in 2013 under CECONY’s steam rate plan.
Depreciation and amortization increased $11 million due to higher steam utility plant balances.
Taxes, other than income taxes decreased $24 million principally due to lower property taxes and sales and use tax refund.
Taxes, Other Than Income Taxes
At $1.8 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:

57



 
For the Years Ended December 31,
 
(Millions of Dollars)
2014
 
2013
 
Variation
Property taxes
$1,406
 
$1,408
 
$(2)
State and local taxes related to revenue receipts
332
 
328
 
4
Payroll taxes
65
 
63
 
2
Other taxes
(5)
(a)
17
 
(22)
Total
$1,798
(b)
$1,816
(b) 
$(18)
(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 2014 and 2013 were $2,267 million and $2,255 million, respectively.
Other Income (Deductions)
Other income (deductions) increased $10 million in 2014 compared with 2013 due primarily to the gain on sale of certain non-utility property.
Net Interest Expense
Net interest expense increased $16 million in 2014 compared with 2013 due primarily to higher interest charges on long-term debt in 2014.
Income Tax Expense
Income taxes increased $35 million in 2014 compared with 2013 due primarily to higher income before income tax expense ($29 million) and higher amortization of New York State’s Metropolitan Transportation Authority business tax ($6 million).
O&R
  
For the Year Ended
December 31, 2014
  
For the Year Ended
December 31, 2013
  
  
(Millions of Dollars)
Electric
Gas
2014
Total
Electric
Gas
2013
Total
2014-2013
Variation
Operating revenues
$680
$212
$892
$628
$205
$833
$59
Purchased power
238

238
217

217
21
Gas purchased for resale

88
88

76
76
12
Other operations and maintenance
251
67
318
238
64
302
16
Depreciation and amortization
46
15
61
41
15
56
5
Taxes, other than income taxes
43
17
60
45
17
62
(2)
Operating income
$102
$25
$127
$87
$33
$120
$7
Electric
O&R’s results of electric operations for the year ended December 31, 2014 compared with the year ended December 31, 2013 is as follows:
  
For the Years Ended December 31,
  
(Millions of Dollars)
2014
2013
Variation
Operating revenues
$680
$628
$52
Purchased power
238
217
21
Other operations and maintenance
251
238
13
Depreciation and amortization
46
41
5
Taxes, other than income taxes
43
45
(2)
Electric operating income
$102
$87
$15

58




O&R’s electric sales and deliveries in 2014 compared with 2013 were:
  
Millions of kWh Delivered
 
Revenues in Millions (a)
  
For the Years Ended
  
 
For the Years Ended
  
Description
December 31, 2014
December  31, 2013
Variation
Percent
Variation
 
December  31, 2014
December 31, 2013
Variation
Percent
Variation
Residential/Religious (b)
1,515

1,580

(65
)
(4.1
)%
 
$307
$287
$20
7.0
%
Commercial/Industrial
812

871

(59
)
(6.8
)
 
136
129
7
5.4

Retail choice customers
3,240

3,166

74

2.3

 
207
192
15
7.8

Public authorities
102

104

(2
)
(1.9
)
 
12
11
1
9.1

Other operating revenues (c)




 
18
9
9
Large

Total
5,669

5,721

(52
)
(0.9
)%
(d)
$680
$628
$52
8.3
%
(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 and Pennsylvania 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 increased.0.2 percent in 2014 compared with 2013.
Operating revenues increased $52 million in 2014 compared with 2013 due primarily to higher purchased power expenses ($21 million) and higher revenues from the New York electric rate plan ($17 million).
Purchased power expenses increased $21 million in 2014 compared with 2013 due to an increase in unit costs ($26 million), offset by a decrease in purchased volumes ($5 million).
Other operations and maintenance expenses increased $13 million due primarily to an increase in surcharges for assessments and fees that are collected in revenues from customers ($5 million), increase in storm costs ($3 million) and higher healthcare costs ($1 million).
Depreciation and amortization increased $5 million due primarily to higher electric utility plant balances.
Taxes, other than income taxes decreased $2 million principally due to lower state revenue taxes.
Gas
O&R’s results of gas operations for the year ended December 31, 2014 compared with the year ended December 31, 2013 is as follows:
  
For the Years Ended December 31,
  
(Millions of Dollars)
2014
2013
Variation
Operating revenues
$212
$205
$7
Gas purchased for resale
88
76
12
Other operations and maintenance
67
64
3
Depreciation and amortization
15
15

Taxes, other than income taxes
17
17

Gas operating income
$25
$33
$(8)

59



O&R’s gas sales and deliveries, excluding off-system sales, in 2014 compared with 2013 were:
  
Thousands of Dt Delivered
 
Revenues in Millions (a)
  
For the Years Ended
  
 
For the Years Ended
  
Description
December 31, 2014
December 31, 2013
Variation
Percent
Variation
 
December 31, 2014
December 31, 2013
Variation
Percent
Variation
Residential
7,786

7,253

533

7.3
%
 
$101
$97
$4
4.1
%
General
1,743

1,555

188

12.1

 
20
18
2
11.1

Firm transportation
12,592

12,062

530

4.4

 
75
77
(2)
(2.6
)
Total firm sales and transportation
22,121

20,870

1,251

6.0

(b) 
196
192
4
2.1

Interruptible sales
4,216

4,118

98

2.4

 
2
3
(1)
(33.3
)
Generation plants
70

19

51

Large

 
1

1
Large

Other
945

885

60

6.8

 




Other gas revenues




 
13
10
3
30.0

Total
27,352

25,892

1,460

5.6
%
 
$212
$205
$7
3.4
%
(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 1.9 percent in 2014 compared with 2013.
Operating revenues increased $7 million in 2014 compared with 2013 due primarily to the increase in gas purchased for resale ($12 million).
Gas purchased for resale increased $12 million in 2014 compared with 2013 due to an increase in unit costs ($6 million) and purchased volumes ($6 million).
Other operations and maintenance expenses increased $3 million due primarily to an increase in surcharges for assessments and fees that are collected in revenues from customers.
Taxes, Other Than Income Taxes
Taxes, other than income taxes, decreased $2 million in 2014 compared with 2013. The principal components of taxes, other than income taxes, were:
 
For the Years Ended December 31,
 
 
(Millions of Dollars)
2014
 
2013
 
Variation
Property taxes
$44
 
$43
 
$1
State and local taxes related to revenue receipts
9
 
12
 
(3)
Payroll taxes
7
 
7
 

Total
$60
(a) 
$62
(a) 
$(2)
(a)
Including sales tax on customers’ bills, total taxes other than income taxes in 2014 and 2013 were $86 million and $87 million, respectively.

Other Income (Deductions)
Other income (deductions) increased $2 million in 2014 compared with 2013 due primarily to higher interest accrued on storm reserves in 2014.
Net Interest Expense
Net interest expense decreased $2 million in 2014 compared with 2013 reflecting primarily changes to accrued interest resulting from adjustments to prior year federal income tax returns in 2013.
Income Tax Expense
Income taxes increased $16 million in 2014 compared with 2013 due primarily to higher income before income tax expense ($5 million), higher amortization of New York State’s Metropolitan Transportation Authority business tax ($3 million) and changes in estimates of accumulated deferred income taxes in 2013 ($6 million).

60




Competitive Energy Businesses
The competitive energy businesses’ results of operations for the year ended December 31, 2014 compared with the year ended December 31, 2013 is as follows:
  
For the Years Ended December 31,
  
(Millions of Dollars)
2014
2013
Variation
Operating revenues
$1,244
$1,096
$148
Purchased power
1,088
861
227
Gas purchased for resale
115
27
88
Other operations and maintenance
108
105
3
Depreciation and amortization
19
23
(4)
Taxes, other than income taxes
19
17
2
(Gain) on sale of solar electric production projects
(45)

(45)
Operating income (loss)
$(60)
$63
$(123)
Operating revenues increased $148 million in 2014 compared with 2013, due primarily to higher wholesale and electric retail revenues ($125 million) and the impact of the LILO transactions ($27 million, see “Lease In/Lease Out Transactions” in Note J to the financial statements in Item 8). Wholesale revenues increased $80 million in 2014 as compared to 2013 due to higher sales volume. Electric retail revenues increased $45 million due to higher unit prices ($64 million), offset by lower sales volumes ($19 million). Solar revenues decreased $14 million in 2014 as compared with 2013 primarily due to Con Edison Development’s sale of 50 percent of its membership interest in CED California Holdings Financing I, LLC (California Solar – see Note Q to the financial statements in Item 8). Net mark-to-market values decreased $202 million in 2014 as compared with 2013, of which $206 million in losses are reflected in purchased power expenses and $4 million in gains are reflected in revenues. Other revenues increased $6 million in 2014 as compared with 2013, due primarily to higher energy services revenues.
Purchased power expenses increased $227 million in 2014 compared with 2013 due primarily to changes in mark-to-market losses ($206 million) and higher unit prices ($64 million), offset by lower volumes ($43 million).
Gas purchased for resale increased $88 million due primarily to higher volumes.
Other operations and maintenance expenses increased $3 million due primarily to an increase in solar electric production projects in operation during 2014.
Depreciation and maintenance expense decreased $4 million due to Con Edison Development’s sale of 50 percent of its membership interest in California Solar (see Note Q to the financial statements in Item 8).
Taxes, other than income taxes increased $2 million due to an increase in sales and use taxes, property taxes and gross receipts tax.
Gain on sale of solar electric production projects was $45 million reflecting Con Edison Development’s sale 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 $20 million in 2014 compared to 2013 primarily reflecting income from Con Edison Development’s solar investments that are accounted for under the equity method.
Net Interest Expense
Net interest expense decreased $143 million in 2014 compared to 2013 due primarily to the impact of the LILO transactions. See “Lease In/Lease Out Transactions” in Note J to the financial statements in Item 8.
Income Tax Expense
Income taxes increased $34 million in 2014 compared with 2013 due primarily to higher income before income tax expense ($17 million) and a tax benefit in 2013 resulting from the acceptance by the IRS of the company’s claim for manufacturing tax deductions ($15 million).
Other
For Con Edison, “Other” also includes intercompany eliminations relating to operating revenues and operating expenses.

61



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 and the competitive energy businesses, 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, 2015, 2014 and 2013 are summarized as follows:
Con Edison
(Millions of Dollars)
2015
2014
Variance
2015 vs.
2014
2013
Variance
2014 vs.
2013
Operating activities
$3,277
$2,831
$446
$2,552
$279
Investing activities
(3,657)
(2,759)
(898)
(2,659)
(100)
Financing activities
629
(47)
676
387
(434)
Net change for the period
249
25
224
280
(255)
Balance at beginning of period
699
674
25
394
280
Balance at end of period
948
699
249
674
25
Less: Held for sale
4

4


Balance at the end of the period excluding held for sale
$944
$699
$245
$674
$25
CECONY
(Millions of Dollars)
2015
2014
Variance
2015 vs.
2014
2013
Variance
2014 vs.
2013
Operating activities
$2,819
$2,430
$389
$2,643
$(213)
Investing activities
(2,638)
(2,304)
(334)
(2,417)
113
Financing activities
17
(114)
131
54
(168)
Net change for the period
198
12
186
280
(268)
Balance at beginning of period
645
633
12
353
280
Balance at end of period
$843
$645
$198
$633
$12
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, economic conditions and measures that promote distributed energy resources. Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans, changes in delivery volumes from levels assumed when rates were approved may affect the timing of cash flows but generally not net income. 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

62




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 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 reflect 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.
Net cash flows from operating activities in 2014 for Con Edison and CECONY were $279 million higher and $213 million lower, respectively, than in 2013. The increase in net cash flows for Con Edison reflects primarily the decreased pension contributions ($303 million) in 2014. The decrease in net cash flows for CECONY reflects higher income tax payments ($585 million) in 2014, offset in part by decreased pension contributions ($286 million) in 2014.
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 $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).
Net cash flows used in investing activities for Con Edison and CECONY were $100 million higher and $113 million lower, respectively, in 2014 than in 2013. For Con Edison, the change reflects primarily the proceeds from the termination of the LILO transactions in 2013 ($200 million) and increased investments in renewable electric production projects ($108 million), offset by proceeds from sale relating to its solar electric production projects in 2014 ($108 million, see Note Q to the financial statements in Item 8). In addition, the changes for Con Edison and CECONY reflect decreased utility construction expenditures in 2014.
Cash Flows From Financing Activities
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 in 2014 for Con Edison and CECONY were $434 million and $168 million lower, respectively, than in 2013.
Net cash flows from financing activities during the years ended December 31, 2015, 2014 and 2013 reflect the following CECONY transactions:
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.

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2014
Issued $850 million of 4.45 percent 30-year debentures, $250 million of 3.30 percent 10-year debentures and $750 million of 4.625 percent 40-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.
2013
Issued $700 million of 3.95 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 $500 million of 4.875 percent 10-year debentures; and
Redeemed at maturity $200 million of 3.85 percent 10-year debentures.
Con Edison's net cash flows from financing activities during the year ended December 31, 2015 also reflect the following O&R transactions:
2015
Issued $120 million of 4.95 percent 30-year debentures and $100 million of 4.69 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 issuances of long-term debt in 2014 and 2013.

In 2015, a Con Edison Development subsidiary issued $118 million aggregate principal amount of 3.94 percent Senior Notes maturing in 2036 and another subsidiary issued $159 million aggregate principal amount of 4.53 percent Senior Notes maturing in 2040. In 2013, a Con Edison Development subsidiary issued $219 million aggregate principal amount of 4.78 percent senior notes secured by certain of the company’s California solar electric production projects. The notes have a weighted average life of 15 years and final maturity of 2037. In 2014, the company sold a 50 percent interest in the subsidiary. See Note Q to the financial statements in Item 8.

Cash flows from financing activities of the Companies also reflect commercial paper issuance. The commercial paper amounts outstanding at December 31, 2015, 2014 and 2013 and the average daily balances for 2015, 2014 and 2013 for Con Edison and CECONY were as follows:
  
2015
2014
2013
(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
$1,529
$823
$801
$899
$1,451
$901
CECONY
$1,033
$379
$451
$765
$1,210
$598
Weighted average yield
0.7
%
0.4
%
0.4
%
0.2
%
0.2
%
0.3
%
Common stock issuances and external borrowings are sources of liquidity that could be affected by changes in credit ratings, financial performance and capital market conditions. For information about the Companies’ credit ratings and certain financial ratios, see “Capital Requirements and Resources” in Item 1.
Capital Requirements and Resources
For information about capital requirements, contractual obligations and capital resources, see “Capital Requirements and Resources” in Item 1.


64




Other Changes in Assets and Liabilities
The following table shows changes in certain assets and liabilities at December 31, 2015, compared with December 31, 2014.
 
Con Edison
CECONY
(Millions of Dollars)
2015 vs. 2014
Variance
2015 vs. 2014
Variance
Assets
 
 
Non-utility property, less accumulated depreciation
$444

Assets held for sale
157

Regulatory asset – Unrecognized pension and other postretirement costs
(970)
$(912)
Liabilities
 
 
Deferred income taxes and investment tax credits
$589
$592
Liabilities held for sale
89

Pension and retiree benefits
(1,003)
(928)
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 "Competitive Energy Businesses - Con Edison Development" and "Capital Requirements and Resources - Capital Requirements" in Item 1.
Assets Held for Sale and Liabilities Held for Sale
The increase in assets held for sale and liabilities held for sale reflects Con Edison's plan to sell the retail electric supply business of its competitive energy businesses and O&R's entry into an agreement to sell Pike. See 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 amortization of accounting costs during the year. The change in the regulatory assets also reflects the final actuarial valuation of the pension and other retiree benefit plans as measured at December 31, 2015, in accordance with the accounting rules for retirement benefits. The change in the liability for pension and retiree benefits reflects in part contributions to the plans made by the Utilities in 2015. 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 reflects primarily accelerated tax deductions for plant, as well as investment tax credits primarily related to Con Edison's renewable electric production projects at its competitive energy businesses. See Note L to the financial statements in Item 8.
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, derivative instruments and leases.
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.

65



The accounting rules for regulated operations specify the economic effects that result from the causal relationship of costs and revenues in the rate-regulated environment and how these effects are to be accounted for by a regulated enterprise. Revenues intended to cover some costs may be recorded either before or after the costs are incurred. If regulation provides assurance that incurred costs will be recovered in the future, these costs would be recorded as deferred charges or “regulatory assets” under the accounting rules for regulated operations. If revenues are recorded for costs that are expected to be incurred in the future, these revenues would be recorded as deferred credits or “regulatory liabilities” under the accounting rules for regulated operations.
The Utilities’ principal regulatory assets and liabilities are listed in Note B to the financial statements in Item 8. The Utilities are 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, 2015, the regulatory assets for Con Edison and CECONY were $8,228 million and $7,603 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. Con Edison’s competitive 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 2015, 2014 and 2013.
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 2016 are decreases, compared with 2015, in their pension and other postretirement benefits costs of $266 million and $251 million, respectively.
 
The following table illustrates the effect on 2016 pension and other postretirement costs of changing the critical actuarial assumptions, while holding all other actuarial assumptions constant:

66




Actuarial Assumption
Change in
Assumption
Pension
Other
Postretirement
Benefits
Total
 
 
(Millions of Dollars)
Increase in accounting cost:
 
 
 
 
Discount rate
 
 
 
 
Con Edison
(0.25
)%
$58
$3
$61
CECONY
(0.25
)%
$54
$2
$56
Expected return on plan assets
 
 
 
 
Con Edison
(0.25
)%
$29
$2
$31
CECONY
(0.25
)%
$28
$2
$30
Health care trend rate
 
 
 
 
Con Edison
1.00
%

$—

$(3)
$(3)
CECONY
1.00
%

$—

$(7)
$(7)
Increase in projected benefit obligation:
 
 
 
 
Discount rate
 
 
 
 
Con Edison
(0.25
)%
$560
$36
$596
CECONY
(0.25
)%
$528
$29
$557
Health care trend rate
 
 
 
 
Con Edison
1.00
%

$—

$(18)
$(18)
CECONY
1.00
%

$—

$(37)
$(37)
A 5.0 percentage point variation in the actual annual return in 2016, as compared with the expected annual asset return of 7.80 percent, would change pension and other postretirement benefit costs for Con Edison and CECONY by approximately $38 million and $36 million, respectively, in 2017.
Pension benefits are provided through a pension plan maintained by Con Edison to which CECONY, O&R and the competitive 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 2015 under funding regulations and tax laws. However, CECONY and O&R made discretionary contributions to the pension plan in 2015 of $697 million and $53 million, respectively. In 2016, CECONY and O&R expect to make contributions to the pension plan of $469 million and $38 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 generally recover costs for asbestos lawsuits, workers’ compensation and environmental remediation pursuant to their current rate plans. 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 Assets
The accounting rules for property, plant and equipment require that certain long-lived assets must be tested for recoverability whenever events or changes in circumstances indicate their carrying amounts may not be recoverable. The carrying amount of a long-lived asset 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 2014 and 2013.
Accounting for Goodwill
In accordance with the accounting rules for goodwill and intangible assets, Con Edison is required to test goodwill for impairment annually. See Note K to the financial statements in Item 8. Goodwill is tested for impairment using a two-step 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 $429 million at December 31, 2015, which consists of $406 million related to the O&R merger and $23 million related to two energy services companies acquired by Con Edison Solutions and a gas storage company acquired by Con Edison Development. The most recent tests, which were performed during 2015, did not require any second-step assessment and did not result in any impairment. Con Edison's most significant assumptions surrounding the goodwill impairment tests relate to the estimates of reporting unit fair values. The company estimated fair values based primarily on discounted cash flows and on market values 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 energy services companies and gas storage company 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 and interest rate risk on certain debt securities. The Utilities are permitted by their respective regulators to reflect in rates all reasonably incurred gains and losses on these instruments. 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.
Accounting for Leases
The Companies apply the accounting rules for leases and other related pronouncements to their leasing transactions. In accordance with the accounting rules, Con Edison accounted for Con Edison Development’s two “Lease In/Lease Out” or LILO transactions as leveraged leases. In 2013, a court disallowed tax losses claimed by Con Edison relating to Con Edison Development’s LILO transactions and the company subsequently terminated the transactions, resulting in charges to earnings of $95 million (after taxes of $63 million) and $1 million in 2013 and 2014, respectively. The transactions had an immaterial impact to earnings in 2015. See Notes J and L to the financial statements in Item 8.

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

68




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, 2015, a 10 percent increase in interest rates applicable to its variable rate debt would result in an increase in annual interest expense of $1 million. Under CECONY’s current gas, steam and electric 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 Con Edison’s competitive 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, 2015, a 10 percent decline in market prices would result in a decline in fair value of $91 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which $82 million is for CECONY and $9 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.
Con Edison’s competitive 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. 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, 2015 and 2014, respectively, was as follows:
95% Confidence Level, One-Day Holding Period
2015
2014
 
(Millions of Dollars)
Average for the period
$1
$1
High
2
7
Low



The competitive energy businesses 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. The stress test includes an assessment of the impact of volume changes on the portfolio because the businesses generally commit to sell their customers their actual requirements, an amount which is estimated when the sales commitments are made. The businesses limit the volume of commodity derivative instruments entered into relative to their estimated sale commitments to maintain net market price exposures to their estimated sale commitments within a certain percentage of maximum and minimum exposures.
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 competitive energy businesses. See “Credit Exposure” in Note O to the financial statements in Item 8.

69



Investment Risk
The Companies’ investment risk relates to the investment of plan assets for their pension and other postretirement benefit plans. See “Application of Critical Accounting Policies – Accounting for Pensions and Other Postretirement Benefits,” above and Notes E and F to the financial statements in Item 8. The Companies’ current investment policy for pension plan assets includes investment targets of 55 to 65 percent equities and 35 to 45 percent fixed income and other securities. At December 31, 2015, the pension plan investments consisted of 57 percent equity and 43 percent fixed income and other securities.
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).
 

70




Item 8:    Financial Statements and Supplementary Data
Financial Statements
Page
 
 
 
 
 
 
 
 
 
Con Edison
 
CECONY
 
All other schedules are omitted because they are not applicable or the required information is shown in financial statements or notes thereto.
 

71



Supplementary Financial Information
Selected Quarterly Financial Data for the years ended December 31, 2015 and 2014 (Unaudited)
 
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
 
 
2014
Con Edison
First
Quarter
Second
Quarter
Third
Quarter
Fourth
Quarter
 
(Millions of Dollars, except per share amounts)
Operating revenues
$3,789
$2,911
$3,390
$2,829
Operating income
685
455
819
250
Net income (a)
361
212
436
81
Basic earnings per share
$1.23
$0.73
$1.49
$0.28
Diluted earnings per share
$1.23
$0.72
$1.48
$0.28
(a)
Reflects after-tax gain (or charge) in the first and fourth quarter of $7 million and $(8) million, respectively, relating to Con Edison Development’s LILO transactions and in the second quarter of $26 million after-tax relating to its sale of solar electric production projects. For additional information about the LILO transactions and the solar electric production projects, see Note J and Q, respectively, to the financial statements in Item 8 (which information is incorporated herein by reference).
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.
 
 
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
 
 
2014
CECONY
First
Quarter
Second
Quarter
Third
Quarter
Fourth
Quarter
 
(Millions of Dollars)
Operating revenues
$3,204
$2,436
$2,838
$2,308
Operating income
643
386
756
354
Net income
334
172
399
153
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.

72





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, 2015, 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, 2015.
The effectiveness of the Company’s internal control over financial reporting as of December 31, 2015, 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 18, 2016
 

73



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, 2015 and 2014, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2015 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, 2015, 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 18, 2016
 


74




Consolidated Edison, Inc.
Consolidated Income Statement
 
 
For the Years Ended December 31,
(Millions of Dollars/Except Share Data)
2015
 
2014
 
2013
OPERATING REVENUES
 
 
 
 
 
Electric
$8,832
 
$9,114
 
$8,756
Gas
1,709
 
1,933
 
1,821
Steam
629
 
628
 
683
Non-utility
1,384
 
1,244
 
1,094
TOTAL OPERATING REVENUES
12,554
 
12,919
 
12,354
OPERATING EXPENSES
 
 
 
 
 
Purchased power
2,973
 
3,417
 
3,099
Fuel
248
 
285
 
320
Gas purchased for resale
495
 
811
 
635
Other operations and maintenance
3,344
 
3,294
 
3,137
Depreciation and amortization
1,130
 
1,071
 
1,024
Taxes, other than income taxes
1,937
 
1,877
 
1,895
TOTAL OPERATING EXPENSES
10,127
 
10,755
 
10,110
Gain on sale of solar electric production projects

 
45
 

OPERATING INCOME
2,427
 
2,209
 
2,244
OTHER INCOME (DEDUCTIONS)
 
 
 
 
 
Investment and other income
35
 
54
 
24
Allowance for equity funds used during construction
5
 
2
 
4
Other deductions
(16)
 
(14)
 
(15)
TOTAL OTHER INCOME
24
 
42
 
13
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE
2,451
 
2,251
 
2,257
INTEREST EXPENSE
 
 
 
 
 
Interest on long-term debt
632
 
587
 
578
Other interest
24
 
5
 
143
Allowance for borrowed funds used during construction
(3)
 
(1)
 
(2)
NET INTEREST EXPENSE
653
 
591
 
719
INCOME BEFORE INCOME TAX EXPENSE
1,798
 
1,660
 
1,538
INCOME TAX EXPENSE
605
 
568
 
476
NET INCOME
$1,193
 
$1,092
 
$1,062
Net income per common share — basic
$4.07
 
$3.73
 
$3.62
Net income per common share — diluted
$4.05
 
$3.71
 
$3.61
DIVIDENDS DECLARED PER COMMON SHARE
$2.60
 
$2.52
 
$2.46
AVERAGE NUMBER OF SHARES OUTSTANDING — BASIC (IN MILLIONS)
293.0
 
292.9
 
292.9
AVERAGE NUMBER OF SHARES OUTSTANDING — DILUTED (IN MILLIONS)
294.4
 
294.0
 
294.4
The accompanying notes are an integral part of these financial statements.
 

75



Consolidated Edison, Inc.
Consolidated Statement of Comprehensive Income
 
  
For the Years Ended December 31,
(Millions of Dollars)
2015
 
2014
 
2013
NET INCOME
$1,193
 
$1,092
 
$1,062
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
 
 
 
 
 
Pension and other postretirement benefit plan liability adjustments, net of taxes
11
 
(20)
 
28
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
11
 
(20)
 
28
COMPREHENSIVE INCOME
$1,204
 
$1,072
 
$1,090
The accompanying notes are an integral part of these financial statements.

76




Consolidated Edison, Inc.
Consolidated Statement of Cash Flows
  
For the Years Ended December 31,
(Millions of Dollars)
2015
 
2014
 
2013
OPERATING ACTIVITIES
 
 
 
 
 
Net Income
$1,193
 
$1,092
 
$1,062
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
 
 
 
 
 
Depreciation and amortization
1,130
 
1,071
 
1,024
Deferred income taxes
653
 
518
 
40
Rate case amortization and accruals
(52)
 
121
 
21
Common equity component of allowance for funds used during construction
(5)
 
(2)
 
(4)
Net derivative (gains)/losses
3
 
128
 
(74)
Pre-tax gains on termination of LILO transactions

 

 
(95)
Pre-tax gain on sale of solar electric production projects

 
(45)
 

Other non-cash items, net
77
 
(35)
 
91
CHANGES IN ASSETS AND LIABILITIES
 
 
 
 
 
Accounts receivable - customers
96
 
44
 
(29)
Special deposits
5
 
312
 
(257)
Materials and supplies, including fuel oil and gas in storage
22
 
(10)
 
(33)
Other receivables and other current assets
(32)
 
4
 
34
Income taxes receivable
58
 
(224)
 

Prepayments
(14)
 
(27)
 
23
Accounts payable
(79)
 
(9)
 
(118)
Pensions and retiree benefits obligations, net
756
 
822
 
829
Pensions and retiree benefits contributions
(756)
 
(584)
 
(887)
Accrued taxes
(10)
 
(404)
 
314
Accrued interest
4
 
(113)
 
96
Superfund and environmental remediation costs, net
22
 
28
 
(4)
Distributions from equity investments
31
 

 

Deferred charges, noncurrent assets and other regulatory assets
(111)
 
(361)
 
(162)
Deferred credits and other regulatory liabilities
182
 
498
 
637
Other current and noncurrent liabilities
104
 
7
 
44
NET CASH FLOWS FROM OPERATING ACTIVITIES
3,277
 
2,831
 
2,552
INVESTING ACTIVITIES
 
 
 
 
 
Utility construction expenditures
(2,562)
 
(2,239)
 
(2,339)
Cost of removal less salvage
(219)
 
(216)
 
(217)
Non-utility construction expenditures
(492)
 
(180)
 
(199)
Investments in/acquisitions of renewable electric production projects
(299)
 
(293)
 
(175)
Proceeds from grants related to solar electric production projects

 
36
 
93
Proceeds from sale of solar electric production projects

 
108
 

Restricted cash
(13)
 
15
 
(22)
Proceeds from the termination of LILO transactions

 

 
200
Other investing activities
(72)
 
10
 

NET CASH FLOWS USED IN INVESTING ACTIVITIES
(3,657)
 
(2,759)
 
(2,659)
FINANCING ACTIVITIES
 
 
 
 
 
Net issuance/(payment) of short-term debt
729
 
(651)
 
912
Issuance of long-term debt
1,147
 
1,850
 
919
Retirement of long-term debt
(500)
 
(480)
 
(709)
Debt issuance costs
(15)
 
(17)
 
(6)
Common stock dividends
(733)
 
(739)
 
(721)
Issuance of common shares for stock plans, net of repurchases
1
 
(10)
 
(8)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES
629
 
(47)
 
387
CASH AND TEMPORARY CASH INVESTMENTS:
 
 
 
 
 
NET CHANGE FOR THE PERIOD
249
 
25
 
280
BALANCE AT BEGINNING OF PERIOD
699
 
674
 
394
BALANCE AT END OF PERIOD
948
 
699
 
674
LESS: HELD FOR SALE
4
 

 

BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE
$944
 
$699
 
$674
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
 
 
 
 
 
Cash paid/(received) during the period for:
 
 
 
 
 
Interest
$597
 
$561
 
$574
Income taxes
$(36)
 
$633
 
$69
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
 
 
 
 
 
Construction expenditures in accounts payable
$279
 
$179
 
$174
Issuance of common shares for dividend reinvestment
$28
 
$11
 
$10
The accompanying notes are an integral part of these financial statements.

77



Consolidated Edison, Inc.
Consolidated Balance Sheet
 
(Millions of Dollars)
December 31, 2015
 
December 31, 2014
ASSETS
 
 
 
CURRENT ASSETS
 
 
 
Cash and temporary cash investments
$944
 
$699
Special deposits
3
 
8
Accounts receivable — customers, less allowance for uncollectible accounts of $85 and $96 in 2015 and 2014, respectively
1,052
 
1,201
Other receivables, less allowance for uncollectible accounts of $11 and $10 in 2015 and 2014, respectively
304
 
133
Income taxes receivable
166
 
224
Accrued unbilled revenue
360
 
500
Fuel oil, gas in storage, materials and supplies, at average cost
350
 
372
Prepayments
177
 
163
Regulatory assets
132
 
138
Assets held for sale
157
 

Other current assets
191
 
278
TOTAL CURRENT ASSETS
3,836
 
3,716
INVESTMENTS
884
 
816
UTILITY PLANT, AT ORIGINAL COST
 
 
 
Electric
26,358
 
25,091
Gas
6,858
 
6,102
Steam
2,336
 
2,251
General
2,622
 
2,465
TOTAL
38,174
 
35,909
Less: Accumulated depreciation
8,044
 
7,614
Net
30,130
 
28,295
Construction work in progress
1,003
 
1,031
NET UTILITY PLANT
31,133
 
29,326
NON-UTILITY PLANT
 
 
 
Non-utility property, less accumulated depreciation of $95 and $91 in 2015 and 2014, respectively
832
 
388
Construction work in progress
244
 
113
NET PLANT
32,209
 
29,827
OTHER NONCURRENT ASSETS
 
 
 
Goodwill
429
 
429
Intangible assets, less accumulated amortization of $4 in 2015 and 2014
2
 
3
Regulatory assets
8,096
 
9,142
Other deferred charges and noncurrent assets
186
 
138
TOTAL OTHER NONCURRENT ASSETS
8,713
 
9,712
TOTAL ASSETS
$45,642
 
$44,071
The accompanying notes are an integral part of these financial statements.
 


78




Consolidated Edison, Inc.
Consolidated Balance Sheet
(Millions of Dollars)
December 31, 2015
 
December 31, 2014
LIABILITIES AND SHAREHOLDERS’ EQUITY
 
 
 
CURRENT LIABILITIES
 
 
 
Long-term debt due within one year
$739
 
$560
Notes payable
1,529
 
800
Accounts payable
1,008
 
1,035
Customer deposits
354
 
344
Accrued taxes
62
 
72
Accrued interest
136
 
132
Accrued wages
97
 
95
Fair value of derivative liabilities
66
 
64
Regulatory liabilities
115
 
163
Liabilities held for sale
89
 

Other current liabilities
525
 
492
TOTAL CURRENT LIABILITIES
4,720
 
3,757
NONCURRENT LIABILITIES
 
 
 
Provision for injuries and damages
185
 
182
Pensions and retiree benefits
2,911
 
3,914
Superfund and other environmental costs
765
 
764
Asset retirement obligations
242
 
188
Fair value of derivative liabilities
39
 
13
Deferred income taxes and unamortized investment tax credits
9,537
 
8,948
Regulatory liabilities
1,977
 
1,993
Other deferred credits and noncurrent liabilities
199
 
181
TOTAL NONCURRENT LIABILITIES
15,855
 
16,183
LONG-TERM DEBT
12,006
 
11,546
EQUITY
 
 
 
Common shareholders’ equity
13,052
 
12,576
Noncontrolling interest
9
 
9
TOTAL EQUITY (See Statement of Equity)
13,061
 
12,585
TOTAL LIABILITIES AND EQUITY
$45,642
 
$44,071
The accompanying notes are an integral part of these financial statements.
 



79



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, 2012
293

$32
$4,991
$7,997
23

$(1,037)
$(61)
$(53)
 
$11,869
Net income
 
 
 
1,062
 
 
 
 
 
1,062
Common stock dividends
 
 
 
(721)
 
 
 
 
 
(721)
Issuance of common shares for stock plans, net of repurchases

 
4
 

3

 
 
7
Other comprehensive income
 
 
 
 
 
 
 
28
 
28
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
The accompanying notes are an integral part of these financial statements.
 



80




Consolidated Edison, Inc.
Consolidated Statement of Capitalization
 
  
Shares outstanding
December 31,
 
At December 31,
(In Millions)
2015
 
2014
 
2015
 
2014
TOTAL EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS
293

 
293

 
$13,086
 
$12,621
Pension plan liability adjustments, net of taxes
 
 
 
 
(31)
 
(42)
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
 
 
 
 
(34)
 
(45)
Equity
 
 
 
 
13,052
 
12,576
Noncontrolling interest
 
 
 
 
9
 
9
TOTAL EQUITY (See Statement of Equity)
 
 
 
 
$13,061
 
$12,585
The accompanying notes are an integral part of these financial statements.
 

81



Consolidated Edison, Inc.
Consolidated Statement of Capitalization

LONG-TERM DEBT (Millions of Dollars)
 
  
 
At December 31,
Maturity
Interest Rate
 
Series
 
2015
 
2014
DEBENTURES:
 
 
 
 
 
 
 
2015
5.375%
 
2005C
 

$—

 
$350
2015
5.30
 
2005A
 

 
40
2015
2.50
 
2010A
 

 
55
2016
5.45
 
2006A
 
75
 
75
2016
5.50
 
2006C
 
400
 
400
2016
5.30
 
2006D
 
250
 
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
2024
3.30
 
2014B
 
250
 
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
 

2045
4.95
 
2015A
 
120
 

2045
4.69
 
2015B
 
100
 

2054
4.625
 
2014C
 
750
 
750
TOTAL DEBENTURES
 
 
 
11,110
 
10,685
TRANSITION BONDS:
 
 
 
 
 
 
2019*
5.22%
 
2004-1
 
14
 
18
TOTAL TRANSITION BONDS
 
 
 
14
 
18
 


82




Consolidated Edison, Inc.
Consolidated Statement of Capitalization
 
LONG-TERM DEBT (Millions of Dollars)
 
  
 
At December 31,
Maturity
Interest Rate
 
Series
 
2015
 
2014
TAX-EXEMPT DEBT - Notes issued to New York State Energy Research and Development Authority for Facilities Revenue Bonds**:
 
 
 
 
 
 
2015
 
1995***
 

 
44
2032
0.42%
 
2004B Series 1
 
127
 
127
2034
0.34
 
1999A
 
293
 
293
2035
0.44
 
2004B Series 2
 
20
 
20
2036
0.27
 
2001B
 
98
 
98
2036
0.01
 
2010A
 
225
 
225
2039
0.36
 
2004A
 
98
 
98
2039
0.01
 
2004C
 
99
 
99
2039
0.01
 
2005A
 
126
 
126
TOTAL TAX-EXEMPT DEBT
 
 
 
1,086
 
1,130
Other long-term debt
 
 
 
648
 
380
Unamortized debt expense
 
 
 
(91)
 
(85)
Unamortized debt discount
 
 
 
(22)
 
(22)
TOTAL
 
 
 
 
12,745
 
12,106
Less: Long-term debt due within one year
 
 
 
739
 
560
TOTAL LONG-TERM DEBT
 
 
 
12,006
 
11,546
TOTAL CAPITALIZATION
 
 
 
$25,058
 
$24,122
 *    The final date to pay the entire remaining unpaid principal balance, if any, of all outstanding bonds is May 17, 2021.
**    Rates are to be reset weekly or by auction held every 35 days; December 31, 2015 rates shown.
***    Issued for O&R pollution control financing.


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



83




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, 2015, 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, 2015.
The effectiveness of the Company’s internal control over financial reporting as of December 31, 2015, 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 18, 2016
 



84




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, 2015 and 2014, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2015 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, 2015, 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 18, 2016
 



85



Consolidated Edison Company of New York, Inc.
Consolidated Income Statement
 
  
For the Years Ended December 31,
(Millions of Dollars)
2015
 
2014
 
2013
OPERATING REVENUES
 
 
 
 
 
Electric
$8,172
 
$8,437
 
$8,131
Gas
1,527
 
1,721
 
1,616
Steam
629
 
628
 
683
TOTAL OPERATING REVENUES
10,328
 
10,786
 
10,430
OPERATING EXPENSES
 
 
 
 
 
Purchased power
1,719
 
2,091
 
2,021
Fuel
248
 
285
 
320
Gas purchased for resale
337
 
609
 
532
Other operations and maintenance
2,881
 
2,873
 
2,735
Depreciation and amortization
1,040
 
991
 
946
Taxes, other than income taxes
1,856
 
1,798
 
1,816
TOTAL OPERATING EXPENSES
8,081
 
8,647
 
8,370
OPERATING INCOME
2,247
 
2,139
 
2,060
OTHER INCOME (DEDUCTIONS)
 
 
 
 
 
Investment and other income
5
 
22
 
11
Allowance for equity funds used during construction
4
 
1
 
2
Other deductions
(14)
 
(12)
 
(12)
TOTAL OTHER INCOME (DEDUCTIONS)
(5)
 
11
 
1
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE
2,242
 
2,150
 
2,061
INTEREST EXPENSE
 
 
 
 
 
Interest on long-term debt
567
 
523
 
511
Other interest
19
 
15
 
11
Allowance for borrowed funds used during construction
(2)
 
(1)
 
(1)
NET INTEREST EXPENSE
584
 
537
 
521
INCOME BEFORE INCOME TAX EXPENSE
1,658
 
1,613
 
1,540
INCOME TAX EXPENSE
574
 
555
 
520
NET INCOME
$1,084
 
$1,058
 
$1,020
The accompanying notes are an integral part of these financial statements.
 



86




Consolidated Edison Company of New York, Inc.
Consolidated Statement of Comprehensive Income
 
  
For the Years Ended December 31,
(Millions of Dollars)
2015
 
2014
 
2013
NET INCOME
$1,084
 
$1,058
 
$1,020
OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
 
 
 
 
 
Pension and other postretirement benefit plan liability adjustments, net of taxes
2
 
(5)
 
3
TOTAL OTHER COMPREHENSIVE INCOME/(LOSS), NET OF TAXES
2
 
(5)
 
3
COMPREHENSIVE INCOME
$1,086
 
$1,053
 
$1,023
The accompanying notes are an integral part of these financial statements.
 



87



Consolidated Edison Company of New York, Inc.
Consolidated Statement of Cash Flows
  
For the Years Ended December 31,
(Millions of Dollars)
2015
 
2014
 
2013
OPERATING ACTIVITIES
 
 
 
 
 
Net income
$1,084
 
$1,058
 
$1,020
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
 
 
 
 
 
Depreciation and amortization
1,040
 
991
 
946
Deferred income taxes
449
 
331
 
222
Rate case amortization and accruals
(74)
 
102
 
10
Common equity component of allowance for funds used during construction
(4)
 
(1)
 
(2)
Other non-cash items, net
(27)
 
(33)
 
(80)
CHANGES IN ASSETS AND LIABILITIES
 
 
 
 
 
Accounts receivable - customers
87
 
59
 
(15)
Materials and supplies, including fuel oil and gas in storage
24
 
(12)
 
(15)
Other receivables and other current assets
38
 
48
 
(30)
Accounts receivables from affiliated companies
(58)
 
(13)
 
(58)
Prepayments
13
 
(24)
 
(21)
Accounts payable
(51)
 
(57)
 
(81)
Accounts payable to affiliates
(11)
 
(22)
 
23
Pensions and retiree benefits obligations, net
714
 
742
 
803
Pensions and retiree benefits contributions
(703)
 
(544)
 
(830)
Superfund and environmental remediation costs, net
19
 
32
 
(4)
Accrued taxes
3
 

 
9
Accrued taxes to affiliated companies
(8)
 
(403)
 
198
Accrued interest
1
 
(22)
 
6
Deferred charges, noncurrent assets and other regulatory assets
(150)
 
(334)
 
(148)
Deferred credits and other regulatory liabilities
379
 
475
 
666
Other current and noncurrent liabilities
54
 
57
 
24
NET CASH FLOWS FROM OPERATING ACTIVITIES
2,819
 
2,430
 
2,643
INVESTING ACTIVITIES
 
 
 
 
 
Utility construction expenditures
(2,410)
 
(2,094)
 
(2,207)
Cost of removal less salvage
(212)
 
(210)
 
(210)
Restricted cash
(16)
 

 

NET CASH FLOWS USED IN INVESTING ACTIVITIES
(2,638)
 
(2,304)
 
(2,417)
FINANCING ACTIVITIES
 
 
 
 
 
Net Issuance/(payment) of short-term debt
583
 
(760)
 
789
Issuance of long-term debt
650
 
1,850
 
700
Retirement of long-term debt
(350)
 
(475)
 
(700)
Debt issuance costs
(7)
 
(17)
 
(7)
Capital contribution by parent
13
 

 

Dividend to parent
(872)
 
(712)
 
(728)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES
17
 
(114)
 
54
CASH AND TEMPORARY CASH INVESTMENTS:
 
 
 
 
 
NET CHANGE FOR THE PERIOD
198
 
12
 
280
BALANCE AT BEGINNING OF PERIOD
645
 
633
 
353
BALANCE AT END OF PERIOD
$843
 
$645
 
$633
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
 
 
 
 
 
Cash paid during the period for:
 
 
 
 
 
Interest
$554
 
$504
 
$500
Income taxes
$163
 
$748
 
$163
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
 
 
 
 
 
Construction expenditures in accounts payable
$210
 
$151
 
$116
The accompanying notes are an integral part of these financial statements.

88




Consolidated Edison Company of New York, Inc.
Consolidated Balance Sheet
 
(Millions of Dollars)
December 31, 2015
 
December 31, 2014
ASSETS
 
 
 
CURRENT ASSETS
 
 
 
Cash and temporary cash investments
$843
 
$645
Special deposits
2
 
2
Accounts receivable – customers, less allowance for uncollectible accounts of $80 and $90 in 2015 and 2014, respectively
987
 
1,064
Other receivables, less allowance for uncollectible accounts of $11 and $8 in 2015 and 2014, respectively
70
 
71
Accrued unbilled revenue
327
 
384
Accounts receivable from affiliated companies
190
 
132
Fuel oil, gas in storage, materials and supplies, at average cost
288
 
312
Prepayments
113
 
126
Regulatory assets
121
 
132
Other current assets
131
 
158
TOTAL CURRENT ASSETS
3,072
 
3,026
INVESTMENTS
286
 
271
UTILITY PLANT AT ORIGINAL COST
 
 
 
Electric
24,828
 
23,599
Gas
6,191
 
5,469
Steam
2,336
 
2,251
General
2,411
 
2,265
TOTAL
35,766
 
33,584
Less: Accumulated depreciation
7,378
 
6,970
Net
28,388
 
26,614
Construction work in progress
922
 
971
NET UTILITY PLANT
29,310
 
27,585
NON-UTILITY PROPERTY
 
 
 
Non-utility property, less accumulated depreciation of $25 in 2015 and 2014
5
 
5
NET PLANT
29,315
 
27,590
OTHER NONCURRENT ASSETS
 
 
 
Regulatory assets
7,482
 
8,457
Other deferred charges and noncurrent assets
75
 
99
TOTAL OTHER NONCURRENT ASSETS
7,557
 
8,556
TOTAL ASSETS
$40,230
 
$39,443
The accompanying notes are an integral part of these financial statements.
 


89



Consolidated Edison Company of New York, Inc.
Consolidated Balance Sheet
 
(Millions of Dollars)
December 31, 2015
 
December 31, 2014
LIABILITIES AND SHAREHOLDER’S EQUITY
 
 
 
CURRENT LIABILITIES
 
 
 
Long-term debt due within one year
$650
 
$350
Notes payable
1,033
 
450
Accounts payable
771
 
802
Accounts payable to affiliated companies
12
 
23
Customer deposits
339
 
330
Accrued taxes
49
 
46
Accrued taxes to affiliated companies
2
 
10
Accrued interest
118
 
117
Accrued wages
88
 
84
Fair value of derivative liabilities
50
 
48
Regulatory liabilities
84
 
118
Other current liabilities
443
 
415
TOTAL CURRENT LIABILITIES
3,639
 
2,793
NONCURRENT LIABILITIES
 
 
 
Provision for injuries and damages
178
 
176
Pensions and retiree benefits
2,565
 
3,493
Superfund and other environmental costs
665
 
666
Asset retirement obligations
234
 
185
Fair value of derivative liabilities
36
 
10
Deferred income taxes and unamortized investment tax credits
8,755
 
8,163
Regulatory liabilities
1,789
 
1,837
Other deferred credits and noncurrent liabilities
167
 
144
TOTAL NONCURRENT LIABILITIES
14,389
 
14,674
LONG-TERM DEBT
10,787
 
10,788
COMMON SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)
11,415
 
11,188
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY
$40,230
 
$39,443
The accompanying notes are an integral part of these financial statements.
 



90




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, 2012
235

$589
$4,234
$6,761
$(962)
$(61)
$(9)
$10,552
Net income
 
 
 
1,020
 
 
 
1,020
Common stock dividend to parent
 
 
 
(728)
 
 
 
(728)
Other comprehensive income
 
 
 
 
 
 
3
3
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
The accompanying notes are an integral part of these financial statements.

91



Consolidated Edison Company of New York, Inc.
Consolidated Statement of Capitalization
 
 
Shares outstanding
 
 
  
December 31,
 
December 31,
 
At December 31,
(In Millions)
2015
 
2014
 
2015
 
2014
TOTAL SHAREHOLDER’S EQUITY BEFORE ACCUMULATED OTHER COMPREHENSIVE LOSS
235

 
235

 
$11,424
 
$11,199
Pension plan liability adjustments, net of taxes
 
 
 
 
(6)
 
(8)
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
 
 
 
 
(9)
 
(11)
TOTAL COMMON SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)
 
 
 
 
$11,415
 
$11,188
The accompanying notes are an integral part of these financial statements.
 


92




Consolidated Edison Company of New York, Inc.
Consolidated Statement of Capitalization
LONG-TERM DEBT (Millions of Dollars)
 
  
 
At December 31,
Maturity
Interest Rate
 
Series
 
2015
 
2014
DEBENTURES:
 
 
 
 
 
 
 
2015
5.375%
 
2005C
 

$—

 
$350
2016
5.50
 
2006C
 
400
 
400
2016
5.30
 
2006D
 
250
 
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
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
 

2054
4.625
 
2014C
 
750
 
750
TOTAL DEBENTURES
 
 
 
10,450
 
10,150
TAX-EXEMPT DEBT – Notes issued to New York State Energy Research and Development Authority for Facilities Revenue Bonds*:
 
 
 
 
 
 
2032
0.42%
 
2004B Series 1
 
127
 
127
2034
0.34
 
1999A
 
293
 
293
2035
0.44
 
2004B Series 2
 
20
 
20
2036
0.27
 
2001B
 
98
 
98
2036
0.01
 
2010A
 
225
 
225
2039
0.36
 
2004A
 
98
 
98
2039
0.01
 
2004C
 
99
 
99
2039
0.01
 
2005A
 
126
 
126
TOTAL TAX-EXEMPT DEBT
 
1,086
 
1,086
Unamortized debt expense
 
 
 
(78)
 
(76)
Unamortized debt discount
 
 
 
(21)
 
(22)
TOTAL
 
11,437
 
11,138
Less: Long-term debt due within one year
 
650
 
350
TOTAL LONG-TERM DEBT
 
 
 
10,787
 
10,788
TOTAL CAPITALIZATION
 
$22,202
 
$21,976
*    Rates are to be reset weekly or by auction held every 35 days; December 31, 2015 rates shown.
The accompanying notes are an integral part of these financial statements.

93



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 Con Edison’s other utility subsidiary, Orange and Rockland Utilities, Inc. (O&R), and Con Edison’s competitive energy businesses (discussed below) in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R.
As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself.
Con Edison has two regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiaries, provides electric service in southeastern New York and adjacent areas of northern New Jersey and eastern Pennsylvania (see Note U) and gas service in southeastern New York and adjacent areas of eastern Pennsylvania. Con Edison has the following competitive energy businesses: Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company which sells to retail customers electricity purchased in wholesale markets (see Note U), enters into related hedging transactions and also provides energy-related products and services to retail customers; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects. In addition, in 2014 Con Edison formed Consolidated Edison Transmission LLC (CET Electric) to invest in an electric transmission company. In January 2016, Con Edison transferred CET Electric to another wholly-owned subsidiary of Con Edison, Con Edison Transmission, Inc. (Con Edison Transmission). See information about CET Electric under “Guarantees” in Note H. In January 2016, Con Edison Transmission formed Con Edison Gas Midstream, LLC (CET Gas) to invest in gas transmission projects.
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.

94




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 4.4 percent, 1.6 percent and 4.0 percent for 2015, 2014 and 2013, respectively. The AFUDC rates for O&R were 0.4 percent, 2.6 percent and 5.7 percent for 2015, 2014 and 2013, 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, 3.1 percent and 3.2 percent for 2015, 2014 and 2013, respectively. The average depreciation rates for O&R were 3.0 percent, 2.9 percent and 2.8 percent for 2015, 2014 and 2013, 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, 2015 and 2014, the capitalized cost of the Companies’ utility plant, net of accumulated depreciation, was as follows:
  
                 Con Edison
 
                CECONY
(Millions of Dollars)
2015
 
2014
 
2015
 
2014
Electric
 
 
 
 
 
 
 
Generation
$459
 
$451
 
$459
 
$451
Transmission
3,045
 
2,956
 
2,833
 
2,744
Distribution
17,244
 
16,361
 
16,394
 
15,531
Gas (a)
5,698
 
5,006
 
5,196
 
4,530
Steam
1,849
 
1,795
 
1,849
 
1,795
General
1,758
 
1,650
 
1,592
 
1,498
Held for future use
77
 
76
 
65
 
65
Construction work in progress
1,003
 
1,031
 
922
 
971
Net Utility Plant
$31,133
 
$29,326
 
$29,310
 
$27,585
(a) Primarily distribution.
Under the Utilities’ rate plans, the aggregate annual depreciation allowance in effect at December 31, 2015 was $1,110 million, including $1,050 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 competitive 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.

95



Goodwill
Con Edison tests goodwill for impairment at least annually. 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. See Note K.
Impairments
Con Edison evaluates the impairment of long-lived assets, 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 Pike County Light & Power Company (Pike) assets held for sale. See Note U. No impairment charges on long-lived assets were recognized in 2014 or 2013.
Revenues
The Utilities and Con Edison Solutions recognize 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 and Con Edison Solutions accrue 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)
2015
 
2014
 
2013
Con Edison
$354
 
$365
 
$354
CECONY
331
 
343
 
329
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.

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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’s competitive energy businesses, which are accounted for under the equity method (depending on the subsidiaries’ percentage ownership). Utilities’ investments are recorded at fair value and include the investments of the deferred income plan and the supplemental retirement income plan in trust-owned life insurance assets.
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 (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.

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Federal Income Tax
In accordance with the 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, in accordance with the accounting rules for regulated operations, 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 the 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 tax sharing agreements among the members of the consolidated group. Tax loss 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
Generally 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)
2015
 
2014
 
2013
Con Edison
$23
 
$22
 
$18
CECONY
22
 
20
 
16
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.

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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)
2015
 
2014
 
2013
Net income
$1,193
 
$1,092
 
$1,062
Weighted average common shares outstanding – basic
293.0
 
292.9
 
292.9
Add: Incremental shares attributable to effect of potentially dilutive securities
1.4
 
1.1
 
1.5
Adjusted weighted average common shares outstanding – diluted
294.4
 
294.0
 
294.4
Net Income per common share – basic
$4.07
 
$3.73
 
$3.62
Net Income per common share – diluted
$4.05
 
$3.71
 
$3.61
 
The computation of diluted EPS for the years ended December 31, 2014 and 2013 exclude 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 by Component
Changes to accumulated other comprehensive income (OCI) for Con Edison and CECONY are as follows:
(Millions of Dollars)
Con Edison
 
CECONY
Accumulated OCI, net of taxes, at December 31, 2013
$(25)
 
$(6)
OCI before reclassifications, net of tax of $18 and $4 for Con Edison and CECONY, respectively
(26)
 
(6)
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, 2014
(20)
 
(5)
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)
(a) Tax reclassified from accumulated OCI is reported in the income tax expense line item of the income statement.
(b) For the portion of unrecognized pension and other postretirement benefit costs relating to the regulated 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.

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 O&R’s New Jersey and Pennsylvania (see Note U) regulated utility subsidiaries are approved by utility regulators in those states. 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.

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Common provisions of the Utilities’ 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 for items such as major storm events 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”). The New Jersey Board of Public Utilities (NJBPU) and the Pennsylvania Public Utility Commission (PAPUC) use the rate base balances that would exist at the beginning of the 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
 
April 2010 – December 2013
  
January 2014 – December 2016
Base rate changes (a)
 
Yr. 1 – $420 million
Yr. 2 – $420 million
Yr. 3 – $287 million(b)
  
Yr. 1 – $(76.2) million (c)
Yr. 2 – $124.0 million (c)
Yr. 3 – None
Amortizations to income of net regulatory (assets) and liabilities
 
$(75.3) million over three years
  
Yr. 1 and 2 – $(37) million (d)
Yr. 3 - $123 million (d)
Other revenue sources
 
Retention of $120 million of annual transmission congestion revenues from the sale of transmission rights ($90 million for the period April 1, 2013 to December 31, 2013).
  
Retention of $90 million of annual transmission congestion revenues.
Revenue decoupling mechanisms
 
In 2012 and 2013, the company deferred for customer benefit $59 million and $34 million of revenues, respectively.
  
In 2014 and 2015, the company deferred for customer benefit $146 million and $98 million of revenues, respectively.
Recoverable energy costs
 
Current rate recovery of purchased power and fuel costs.
  
Current rate recovery of purchased power and fuel costs (e).
Negative revenue adjustments
 
Potential penalties (up to $350 million annually) if certain performance targets are not met. In 2012 and 2013, the company did not record any 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, the company did not record any negative revenue adjustments.
Cost reconciliations (f)
 
In 2012 and 2013, the company deferred $146 million of net regulatory liabilities and $35 million of net regulatory assets, respectively.
  
In 2014 and 2015, the company deferred $57 million and $26 million of net regulatory liabilities, respectively.
Net utility plant reconciliations
 
Target levels reflected in rates were: Transmission and distribution:
Yr. 1 – $13,818 million
Yr. 2 – $14,742 million
Yr. 3 – $15,414 million
Enterprise resource project:
Yr. 2 – $25 million; Yr. 3 -$115 million;
Other: Yr. 1 – $1,487 million;
Yr. 2 – $1,565 million; Yr. 3 – $1,650 million
The company deferred an immaterial amount and $7 million as a regulatory liability in 2012 and 2013, respectively.
  
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 an immaterial amount and $17 million as a regulatory liability in 2014 and 2015, respectively.
Average rate base
 
Yr. 1 – $14,887 million
Yr. 2 – $15,987 million
Yr. 3 – $16,826 million
  
Yr. 1 – $17,323 million
Yr. 2 – $18,113 million
Yr. 3 – $18,282 million
Weighted average cost of capital (after-tax)
 
7.76 percent
  
Yr. 1 – 7.05 percent
Yr. 2 – 7.08 percent
Yr. 3 – 6.91 percent
Authorized return on common equity
 
10.15 percent assuming the company achieved austerity measures of $27 million, $20 million and $13 million for Yrs. 1, 2 and 3, respectively. Austerity measures were achieved.
  
Yrs. 1 and 2 – 9.2 percent
Yr. 3 – 9.0 percent
Earnings sharing
 
Actual earnings above an annual earnings threshold of 11.15 percent for Yr. 1 and 10.65 percent for Yrs. 2 and 3 were to be applied to reduce regulatory assets for pensions and other postretirement benefits and other costs. Actual earnings were $17.5 million above the threshold for the period ended 2013.
  
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 above the threshold for 2015.
Cost of long-term debt
 
5.65 percent
  
Yr. 1 – 5.17 percent
Yr. 2 – 5.23 percent
Yr. 3 – 5.09 percent
Common equity ratio
 
48 percent
  
48 percent
(a)
$249 million of annual revenues collected from electric customers will continue to be subject to potential refund following NYSPSC staff review of certain costs. See "Other Regulatory Matters" below. Revenues for 2014 through 2016 will include $21 million as funding for major storm reserve.
(b)
Temporary portion of the increase ($134 million) that was scheduled to go into effect April 1, 2012 was eliminated by the application of available credits.
(c)
The impact of these base rate changes were deferred which resulted in a $30 million regulatory liability at December 31, 2015.
(d)
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 will be amortized to income.
(e)
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. In January 2014, PJM submitted to the FERC a request that would substantially increase the charges for the transmission service. FERC has granted the request and rejected CECONY’s protests. CECONY is challenging the FERC’s decision. In August 2015, PJM submitted a request to FERC that, if

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approved by FERC, would further increase the charges. In January 2016, FERC held a technical conference on this matter. It is anticipated that FERC will issue an order addressing this matter in 2016.
(f)
Deferrals for property taxes are limited to 90 percent (80 percent prior to 2014) 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. 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.
In January 2016, CECONY filed a request with the NYSPSC for an electric rate increase of $482 million, effective January 2017. The filing reflects a return on common equity of 9.75 percent and a common equity ratio of 48 percent.
The company is requesting provisions pursuant to which expenses for pension and other postretirement benefits, variable-rate, tax-exempt long-term debt, storms, property taxes and municipal infrastructure support, the impact of new laws and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is requesting, among other things, full reconciliation for Reforming the Energy Vision (REV) distributed system implementation plan enablement costs and REV demonstration project costs. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers.
The filing includes supplemental information regarding electric rate plans for 2018 and 2019, which the company is not requesting but would consider through settlement discussions. For purposes of illustration, rate increases of $180 million and $141 million effective January 2018 and 2019, respectively, were calculated based upon an assumed return on common equity of 9.75 percent and a common equity ratio of 48 percent.

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CECONY – Gas
 
 
  
 
Effective period
 
October 2010 – December 2013
  
January 2014 – December 2016
Base rate changes (a)
 
Yr. 1 – $47 million
Yr. 2 – $48 million
Yr. 3 – $47 million
  
Yr. 1 – $(54.6) million (b)
Yr. 2 – $38.6 million (b)
Yr. 3 – $56.8 million (b)
Amortizations to income of net
regulatory (assets) and liabilities
 
$(53.1) million over three years
  
$4 million over three years
Other revenue sources
 
Retention of revenues from non-firm customers of up to $58 million and 25 percent of any such revenues above $58 million. The company retained $57 million and $64 million of such revenues in 2012 and 2013, respectively.
  
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 and $66 million of such revenues in 2014 and 2015, respectively.
Revenue decoupling mechanisms
 
In 2012 and 2013, the company deferred $22 million and $36 million of regulatory liabilities, respectively.
  
In 2014 and 2015, the company deferred $28 million and $54 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 $12.6 million annually) if certain gas performance targets are not met. In 2012 and 2013, the company did not record any 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 and 2015, the company did not record any negative revenue adjustments.
Cost reconciliations (c)
 
In 2012 and 2013, the company deferred $9 million and $26 million of net regulatory assets, respectively.
  
In 2014 and 2015, the company deferred $38 million and $11 million of net regulatory liabilities, respectively.
Net utility plant reconciliations
 
Target levels reflected in rates were:
Gas delivery Yr. 1 – $2,934 million;
Yr. 2 – $3,148 million; Yr. 3 – $3,346 million
For 2012 and 2013, $2.9 million and $9.5 million were deferred as a regulatory liability respectively.
  
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
There were no deferrals recorded in 2014. In 2015, $1 million was deferred as a regulatory liability.
Average rate base
 
Yr. 1 – $3,027 million
Yr. 2 – $3,245 million
Yr. 3 – $3,434 million
  
Yr. 1 – $3,521 million
Yr. 2 – $3,863 million
Yr. 3 – $4,236 million
Weighted average cost of capital
(after-tax)
 
7.46 percent
  
Yr. 1 – 7.10 percent
Yr. 2 – 7.13 percent
Yr. 3 – 7.21 percent
Authorized return on common equity
 
9.6 percent assuming the company achieved unspecified austerity measures of $4 million and $2 million in 2012 and 2013. Austerity measures were achieved.
  
9.3 percent
Earnings sharing
 
Actual earnings did not exceed the thresholds of 10.35 percent in Yr. 1 and 10.15 percent in Yrs. 2 and 3.
  
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 and 2015, the company had no earnings above the threshold.
Cost of long-term debt
 
5.57 percent
  
Yr. 1 – 5.17 percent
Yr. 2 – 5.23 percent
Yr. 3 – 5.39 percent
Common equity ratio
 
48 percent
  
48 percent
(a)
$32 million of annual revenues collected from gas customers is subject to potential refund. See “Other Regulatory Matters” below.
(b)
The impact of these base rate changes is being deferred which will result in a $32 million regulatory liability at December 31, 2016.
(c)
Deferrals for property taxes are limited to 90 percent (80 percent prior to 2014) 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.
In January 2016, CECONY filed a request with the NYSPSC for a gas rate increase of $154 million, effective January 2017. The filing reflects a return on common equity of 9.75 percent and a common equity ratio of 48 percent.
The company is requesting provisions pursuant to which expenses for pension and other postretirement benefits, variable-rate, tax-exempt long-term debt, property taxes and municipal infrastructure support, the impact of new laws and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is, among other things, requesting full reconciliation for operations and maintenance costs associated with service line definition changes and proposing a reliability surcharge mechanism to recover costs associated with additional miles of main replacement above the annual targets. The filing also reflects continuation of the

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revenue decoupling mechanism and provisions pursuant to which the company recovers its purchased gas costs from customers.
The filing includes supplemental information regarding gas rate plans for 2018 and 2019, which the company is not requesting but would consider through settlement discussions. For purposes of illustration, rate increases of $97 million and $109 million effective January 2018 and 2019, respectively, were calculated based upon an assumed return on common equity of 9.75 percent and a common equity ratio of 48 percent.
CECONY – Steam
 
 
  
 
Effective period
 
October 2010 – December 2013
  
January 2014 – December 2016
Base rate changes (a)
 
Yr. 1 – $49.5 million
Yr. 2 – $49.5 million
Yr. 3 – $17.8 million
Yr. 3 – $31.7 million collected through a surcharge
  
Yr. 1 – $(22.4) million (b)
Yr. 2 – $19.8 million (b)
Yr. 3 – $20.3 million (b)
Amortizations to income of net
regulatory (assets) and liabilities
 
$(20.1) million over three years
  
$37 million over three years
Recoverable energy costs
 
Current rate recovery of purchased power and fuel 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 2012 and 2013, the company did not record any negative revenue adjustments.
  
Potential penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014 and 2015, the company did not record any negative revenue adjustments.
Cost reconciliations (c)
 
In 2012 and 2013, the company deferred $12 million and $17 million of net regulatory liabilities, respectively.
  
In 2014 and 2015, the company deferred $42 million and $17 million of net regulatory liabilities and assets, respectively.
Net utility plant reconciliations
 
Target levels reflected in rates were:
Production: Yr. 1 – $415 million;
Yr. 2 – $426 million; Yr. 3 – $433 million
Distribution: Yr. 1 – $521 million;
Yr. 2 – $534 million; Yr. 3 – $543 million
The company reduced its regulatory liability by $0.2 million in 2012 and made no deferral in 2013.
  
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 $1.1 million and an immaterial amount in 2014 and 2015, respectively.
Average rate base
 
Yr. 1 – $1,589 million
Yr. 2 – $1,603 million
Yr. 3 – $1,613 million
  
Yr. 1 – $1,511 million
Yr. 2 – $1,547 million
Yr. 3 – $1,604 million
Weighted average cost of capital (after-tax)
 
7.46 percent
  
Yr. 1 – 7.10 percent
Yr. 2 – 7.13 percent
Yr. 3 – 7.21 percent
Authorized return on common equity
 
9.6 percent (assuming company achieved unspecified austerity measures of $3 million and $2 million in 2012 and 2013). Austerity measures were achieved.
  
9.3 percent
Earnings sharing
 
Weather normalized earnings did not exceed the threshold of 10.35 percent in Yr. 1 and 10.15 percent in Yrs. 2 and 3. In 2013, actual earnings were $0.5 million above the earnings threshold of 10.15 percent.
  
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 $17.1 million above the threshold for 2015.
Cost of long-term debt
 
5.57 percent
  
Yr. 1 – 5.17 percent
Yr. 2 – 5.23 percent
Yr. 3 – 5.39 percent
Common equity ratio
 
48 percent
  
48 percent
(a)
$6 million of annual revenues collected from steam customers is subject to potential refund. See “Other Regulatory Matters” below.
(b)
The impact of these base rate changes is being deferred which will result in an $8 million regulatory liability at December 31, 2016.
(c)
Deferrals for property taxes are limited to 90 percent (80 percent prior to 2014) 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.
 
In 2015, the company's deferral for the customer’s benefit was immaterial.
Recoverable energy costs
 
Current rate recovery of purchased power and fuel costs.
 
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.
Cost reconciliations
 
In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase to regulatory assets, respectively.
 
In 2015, the company deferred $1.2 million as a net increase to regulatory assets.
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 its regulatory asset by $2.2 million in 2015.
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.
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 years 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 advanced metering infrastructure 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. 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, the company deferred $0.8 million of regulatory assets.
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, 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, the company deferred $2.5 million as net regulatory assets.
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)
The company recorded no deferrals in 2015.
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.
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 advanced metering infrastructure 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.
Rockland Electric Company (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 will, beginning in 2017, collect through a customer surcharge until a new rate plan is approved that reflects the costs.
 

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Pike – Electric
  
 
Effective period
  
April 2009 – August 2014
 
September 2014 – August 2015
Base rate changes(a)
  
Yr. 1 – $0.9 million
 
Yr. 1 – $1.25 million
Amortization to income of net regulatory (assets) and liabilities
  
$0.1 million over five years
 
$(0.7) million of deferred storm costs over five years
Cost reconciliations
  
True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as regulatory liabilities in 2012 and 2013.
 
True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as a regulatory liability in 2014 and 2015.
(a)
Under the current plan, the earliest that the company can file for a new base rate change is September 1, 2016.
Pike – Gas
  
 
  
 
Effective period
  
April 2009 – August 2014
  
September 2014 – August 2015
Base Rate changes(a)
  
Yr. 1 – $0.3 million
  
Yr. 1 – $0.1 million
Amortization to income of net regulatory (assets) and liabilities
  
None
  
None
Cost reconciliations
  
True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as regulatory liabilities in 2012 and 2013.
  
True-up of Other Postretirement Benefits costs. The company deferred an immaterial amount as a regulatory liability in 2014 and 2015.
(a)
Under the current plan, the earliest that the company can file for a new base rate change is September 1, 2016.
Other Regulatory Matters
In February 2009, the NYSPSC commenced a proceeding to examine the prudence of certain CECONY expenditures following the arrests of employees for accepting illegal payments from a construction contractor. Subsequently, additional employees were arrested for accepting illegal payments from materials suppliers and an engineering firm. The arrested employees were terminated by the company and have pled guilty or been convicted. Pursuant to NYSPSC orders, a portion of the company’s revenues (currently, $249 million, $32 million and $6 million on an annual basis for electric, gas and steam service, respectively) is being collected subject to potential refund to customers. The amount of electric revenues collected subject to refund, which was established in a different proceeding, and the amount of gas and steam revenues collected subject to refund were not established as indicative of the company’s potential liability in this proceeding. At December 31, 2015, the company had collected an estimated $1,962 million from customers subject to potential refund in connection with this proceeding. In January 2013, a NYSPSC consultant reported its estimate, with which the company does not agree, of $208 million of overcharges with respect to a substantial portion of the company’s construction expenditures from January 2000 to January 2009. The company disputed the consultant’s estimate, including its determinations as to overcharges regarding specific construction expenditures it selected to review and its methodology of extrapolating such determinations over a substantial portion of the construction expenditures during this period. The NYSPSC’s consultant has not reviewed the company’s other expenditures. In September 2015, the company, the NYSPSC staff and others entered into a Joint Proposal to settle this proceeding and related matters. The Joint Proposal is subject to NYSPSC approval. Pursuant to the Joint Proposal, the company is required to credit $116 million to customers and, for the period 2017 through 2044, to not seek to recover from customers an aggregate $55 million relating to return on its capital expenditures. In addition, the company’s revenues that were made subject to potential refund in this proceeding would no longer be subject to refund. At December 31, 2015, the company had a $99 million regulatory liability for the remaining amount to be credited to customers related to this matter.
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

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plan. CECONY expects to submit its risk assessment and remediation plan to the NYSPSC staff in 2016. The Companies are unable to estimate the amount or range of their possible loss related to this proceeding.
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. The company is unable to estimate the amount or range of its possible loss related to any such proceedings that may be instituted.


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Regulatory Assets and Liabilities
Regulatory assets and liabilities at December 31, 2015 and 2014 were comprised of the following items:
  
                  Con Edison
                CECONY
(Millions of Dollars)
2015
2014

2015

2014

Regulatory assets
 
 
 
 
Unrecognized pension and other postretirement costs
$3,876
$4,846
$3,697
$4,609
Future income tax
2,350
2,259
2,232
2,142
Environmental remediation costs
904
925
800
820
Revenue taxes
253
219
240
208
Deferred storm costs
185
319
110
224
Unamortized loss on reacquired debt
50
57
48
55
Deferred derivative losses
50
25
46
23
O&R property tax reconciliation
46
36


Pension and other postretirement benefits deferrals
45
66
16
42
Surcharge for New York State assessment
44
99
40
92
Net electric deferrals
44
63
44
63
Preferred stock redemption
26
27
26
27
O&R transition bond charges
21
27


Recoverable energy costs
16
19
15
17
Workers’ compensation
11
8
11
8
Other
175
147
157
127
Regulatory assets – noncurrent
8,096
9,142
7,482
8,457
Deferred derivative losses
113
97
103
92
Recoverable energy costs
19
41
18
40
Regulatory assets – current
132
138
121
132
Total Regulatory Assets
$8,228
$9,280
$7,603
$8,589
Regulatory liabilities
 
 
 
 
Allowance for cost of removal less salvage
$676
$598
$570
$499
Property tax reconciliation
303
295
303
295
Base rate change deferrals
128
155
128
155
Net unbilled revenue deferrals
109
138
109
138
Prudence proceeding
99
105
99
105
Earnings sharing - electric and steam
80
19
80
18
Pension and other postretirement benefit deferrals
76
46
46
37
New York State income tax rate change
75
62
72
59
Variable-rate tax-exempt debt - cost rate reconciliation
70
78
60
78
Carrying charges on repair allowance and bonus depreciation
49
58
48
57
Property tax refunds
44
87
44
87
Net utility plant reconciliations
32
21
31
20
Unrecognized other postretirement costs
28

28

World Trade Center settlement proceeds
21
41
21
41
Other
187
290
150
248
Regulatory liabilities – noncurrent
1,977
1,993
1,789
1,837
Refundable energy costs
64
128
33
84
Revenue decoupling mechanism
45
30
45
30
Deferred derivative gains
6
5
6
4
Regulatory liabilities—current
115
163
84
118
Total Regulatory Liabilities
$2,092
$2,156
$1,873
$1,955
Unrecognized pension and other postretirement costs represents the net regulatory asset associated with the accounting rules for retirement benefits. See Note A.

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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 represents 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 over a ten-year period.
Revenue taxes represents 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 $109 million and $138 million at December 31, 2015 and 2014, respectively, for the difference between the unbilled revenues and energy cost liabilities.
Note C – Capitalization
Common Stock
At December 31, 2015 and 2014, Con Edison owned all of the issued and outstanding shares of common stock of the Utilities, the competitive 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 the Utilities’ outstanding debt.
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 2016-2020 is as follows:
(Millions of Dollars)
Con Edison
 
CECONY

2016
$739
 
$650
2017
16
 

2018
1,266
 
1,200
2019
552
 
475
2020
365
 
350
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, 2015 and 2014 are:
(Millions of Dollars)
2015
 
2014
Long-Term Debt (including current portion)
Carrying
Amount
 
Fair
Value
 
Carrying
Amount
 
Fair
Value
Con Edison
$12,745
 
$13,856
 
$12,106
 
$13,913
CECONY
$11,437
 
$12,427
 
$11,138
 
$12,770
Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, $13,220 million and $636 million of the fair value of long-term debt at December 31, 2015 are classified as Level 2 and Level 3, respectively. For CECONY, $11,791 million and $636 million of the fair value of long-term debt at December 31, 2015 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, 2015 and 2014, long-term debt of Con Edison included $15 million and $18 million, respectively, of Transition Bonds issued in 2004 by O&R’s New Jersey utility subsidiary through a special purpose entity.
Unamortized Debt Issuance Costs
The Companies adopted Accounting Standards Update (ASU) No. 2015-03, “Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs,” as of December 31, 2015, requiring that debt issuance costs be presented as a reduction to the carrying value of the related debt. In prior years, these costs were presented as other assets on the consolidated balance sheet. Prior year consolidated balance sheets have been adjusted retrospectively to conform with the current year presentation. With the adoption of the new pronouncement, unamortized debt issuance costs associated with outstanding long-term debt of $91 million and $85 million for Con Edison and $78 million and $76 million for CECONY as of December 31, 2015 and 2014, respectively, has been reclassified from other assets to a reduction of the carrying value of long-term debt.
Significant Debt Covenants
The significant debt covenants under the financing arrangements for the notes of Con Edison and the debentures of CECONY are obligations to pay principal and interest when due, covenants not to consolidate with or merge into any other corporation unless certain conditions are met and, for Con Edison’s notes, covenants that Con Edison shall continue its utility business in New York City and shall not permit Con Edison's ratio of consolidated debt to consolidated capital to exceed 0.675 to 1. Con Edison’s notes are also subject to cross default provisions with respect to other indebtedness of Con Edison or its material subsidiaries having a then outstanding principal balance in excess of $100 million. CECONY’s debentures have no cross default provisions. The tax-exempt financing arrangements of the Utilities are subject to covenants for the CECONY debentures discussed above and the covenants discussed below. The Companies were in compliance with their significant debt covenants at December 31, 2015.
The tax-exempt financing arrangements involved the issuance of uncollateralized promissory notes of the Utilities 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 the obligated utility will not at any time exceed 0.65 to 1 and that, subject to certain exceptions, the utility will not mortgage, lien, pledge or otherwise encumber its assets. Certain of the facilities also

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include as events of default, defaults in payments of other debt obligations in excess of specified levels ($150 million or $100 million for CECONY, depending on the facility).
Note D – Short-Term Borrowing
In October 2011, Con Edison and the Utilities entered into a credit agreement (Credit Agreement), under which banks are committed to provide loans and letters of credit on a revolving credit basis. The Credit Agreement, as amended, expires in October 2017. There is a maximum of $2.25 billion of credit available through October 2016 and approximately $2.1 billion of credit available from then through October 2017. The full amount is available to CECONY and $1.5 billion is available to Con Edison, including up to $1.2 billion 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, 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, 2014, Con Edison had $800 million of commercial paper outstanding of which $450 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, 2014 was 0.4 percent for both Con Edison and CECONY. At December 31, 2015 and 2014, no loans were outstanding under the Credit Agreement and $15 million and $11 million (including $11 million for CECONY) 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, 2015 this ratio was 0.52 to 1 for Con Edison and 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, 2015.
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 Con Edison’s competitive 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 2015, 2014 and 2013 were as follows:
  
Con Edison
CECONY
(Millions of Dollars)
2015
2014
2013
2015
2014
2013
Service cost – including administrative expenses
$297
$227
$267
$279
$211
$249
Interest cost on projected benefit obligation
575
572
537
538
536
503
Expected return on plan assets
(886)
(832)
(750)
(840)
(789)
(713)
Recognition of net actuarial loss
775
618
832
734
586
788
Recognition of prior service costs
4
4
5
2
2
4
NET PERIODIC BENEFIT COST
$765
$589
$891
$713
$546
$831
Amortization of regulatory asset (a)
1
2
2
1
2
2
TOTAL PERIODIC BENEFIT COST
$766
$591
$893
$714
$548
$833
Cost capitalized
(301)
(225)
(348)
(285)
(212)
(327)
Reconciliation to rate level
(74)
118
(84)
(74)
108
(87)
Cost charged to operating expenses
$391
$484
$461
$355
$444
$419

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(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, 2015, 2014 and 2013 was as follows:
 
Con Edison
CECONY
(Millions of Dollars)
2015

2014
2013

2015

2014

2013

CHANGE IN PROJECTED BENEFIT OBLIGATION
 
 
 
 
 
 
Projected benefit obligation at beginning of year
$15,081
$12,197
$13,406
$14,137
$11,429
$12,572
Service cost – excluding administrative expenses
293
221
259
274
206
241
Interest cost on projected benefit obligation
575
572
537
538
536
503
Net actuarial (gain)/loss
(996)
2,641
(1,469)
(931)
2,484
(1,388)
Plan amendments

6




Benefits paid
(576)
(556)
(536)
(536)
(518)
(499)
PROJECTED BENEFIT OBLIGATION AT END OF YEAR
$14,377
$15,081
$12,197
$13,482
$14,137
$11,429
CHANGE IN PLAN ASSETS
 
 
 
 
 
 
Fair value of plan assets at beginning of year
$11,495
$10,755
$9,135
$10,897
$10,197
$8,668
Actual return on plan assets
126
752
1,310
118
715
1,241
Employer contributions
750
578
879
697
535
819
Benefits paid
(576)
(556)
(536)
(536)
(518)
(499)
Administrative expenses
(36)
(34)
(33)
(35)
(32)
(32)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR
$11,759
$11,495
$10,755
$11,141
$10,897
$10,197
FUNDED STATUS
$(2,618)
$(3,586)
$(1,442)
$(2,341)
$(3,240)
$(1,232)
Unrecognized net loss
$3,909
$4,888
$2,759
$3,704
$4,616
$2,617
Unrecognized prior service costs
16
20
17
3
4
6
Accumulated benefit obligation
12,909
13,454
11,004
12,055
12,553
10,268
The decrease in the pension plan’s projected benefit obligation (due primarily to increased discount rates) was the primary cause of the decreased pension liability at Con Edison and CECONY of $968 million and $899 million, respectively, compared with December 31, 2014. For Con Edison, this decrease in pension liability corresponds with a decrease to regulatory assets of $967 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 $10 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 competitive energy businesses and O&R’s New Jersey and Pennsylvania utility subsidiaries.
For CECONY, the decrease in pension liability corresponds with a decrease to regulatory assets of $911 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 competitive energy businesses.
A portion of the unrecognized net loss and prior service cost for the pension plan, equal to $603 million and $4 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 $570 million and $2 million, respectively, for CECONY.
At December 31, 2015 and 2014, Con Edison’s investments include $243 million and $225 million, respectively, held in external trust accounts for benefit payments pursuant to the supplemental retirement plans. Included in these amounts for CECONY were $221 million and $208 million, respectively. See Note P. The accumulated benefit obligations for the supplemental retirement plans for Con Edison and CECONY were $285 million and $249 million as of December 31, 2015 and $289 million and $250 million as of December 31, 2014, respectively.

113



Assumptions
The actuarial assumptions were as follows: 
 
2015

2014

2013

Weighted-average assumptions used to determine benefit obligations at December 31:
 
 
 
Discount rate
4.25
%
3.90
%
4.80
%
Rate of compensation increase
 
 
 
CECONY
4.25
%
4.25
%
4.35
%
O&R
4.00
%
4.00
%
4.25
%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
 
 
 
Discount rate
3.90
%
4.80
%
4.10
%
Expected return on plan assets
7.80
%
8.00
%
8.00
%
Rate of compensation increase
 
 
 
CECONY
4.25
%
4.35
%
4.35
%
O&R
4.00
%
4.25
%
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)
2016
2017
2018
2019
2020
2021-2025
Con Edison
$614
$636
$658
$680
$701
$3,800
CECONY
572
593
614
635
655
3,548
Expected Contributions
Based on estimates as of December 31, 2015, the Companies expect to make contributions to the pension plans during 2016 of $507 million (of which $469 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 2015, 2014 and 2013, and the target allocation for 2016 are as follows:

114




  
Target
Allocation Range
 
           Plan Assets at December 31,
Asset Category
2016
 
2015

 
2014

 
2013

Equity Securities
55% - 65%
 
57
%
 
58
%
 
60
%
Debt Securities
27% - 33%
 
33
%
 
32
%
 
30
%
Real Estate
8% - 12%
 
10
%
 
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 2016 reflects the results of such a study conducted in 2011.
Individual fund managers operate under written guidelines provided by Con Edison, which cover such areas as investment objectives, performance measurement, permissible investments, investment restrictions, trading and execution, and communication and reporting requirements. Con Edison management regularly monitors, and the named fiduciaries review and report to the Committee regarding, asset class performance, total fund performance, and compliance with asset allocation guidelines. Management changes fund managers and rebalances the portfolio as appropriate. At the direction of the named fiduciaries, such changes are reported to the Committee.
Assets measured at fair value on a recurring basis are summarized below under a three-level hierarchy as defined by the accounting rules for fair value measurements (see Note P).
The fair values of the pension plan assets at December 31, 2015 by asset category are as follows:

115



(Millions of Dollars)
Level 1

 
Level 2

 
Level 3

 
Total
U.S. Equity (a)
$3,106
 

$—

 

$—

 
$3,106
International Equity (b)
2,874
 
346
 

 
3,220
Private Equity (c)

 

 
170
 
170
U.S. Government Issued Debt (d)

 
2,222
 

 
2,222
Corporate Bonds Debt (e)

 
1,356
 

 
1,356
Structured Assets Debt (f)

 
1
 

 
1
Other Fixed Income Debt (g)

 
170
 

 
170
Real Estate (h)

 

 
1,248
 
1,248
Cash and Cash Equivalents (i)
115
 
414
 

 
529
Futures (j)
161
 
132
 

 
293
Hedge Funds (k)

 

 
233
 
233
Total investments
$6,256
 
$4,641
 
$1,651
 
$12,548
Funds for retiree health benefits (l)
(162)
 
(120)
 
(43)
 
(325)
Investments (excluding funds for retiree health benefits)
$6,094
 
$4,521
 
$1,608
 
$12,223
Pending activities (m)
 
 
 
 
 
 
(464)
Total fair value of plan net assets
 
 
 
 
 
 
$11,759
(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)
Private Equity consists of global equity funds that are not exchange-traded.
(d)
U.S. Government Issued Debt includes agency and treasury securities.
(e)
Corporate Bonds Debt consists of debt issued by various corporations.
(f)
Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations.
(g)
Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments.
(h)
Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.
(i)
Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.
(j)
Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.
(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.
The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2015 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)
Beginning Balance as of January 1, 2015
Assets Still Held
at Reporting Date –
Unrealized Gains/
(Losses)
Assets Sold
During the
Year – Realized
Gains/(Losses)
Purchases
Sales and
Settlements
Transfer
In/(Out) of
Level 3
Ending Balance as of December 31, 2015
Real Estate
$1,137
$131
$12
$(32)

$—

$1,248
Private Equity
114
17

39

170
Hedge Funds
224
3

6

233
Total investments
$1,475
$151
$12
$13

$—

$1,651
Funds for retiree health benefits
(43)




(43)
Investments (excluding funds for retiree health benefits)
$1,432
$151
$12
$13

$—

$1,608

116




The fair values of the pension plan assets at December 31, 2014 by asset category are as follows:
(Millions of Dollars)
Level 1

 
Level 2

 
Level 3

 
Total
U.S. Equity (a)
$3,168
 

$—

 

$—

 
$3,168
International Equity (b)
2,841
 
361
 

 
3,202
Private Equity (c)

 

 
114
 
114
U.S. Government Issued Debt (d)

 
2,113
 

 
2,113
Corporate Bonds Debt (e)

 
1,351
 

 
1,351
Structured Assets Debt (f)

 
4
 

 
4
Other Fixed Income Debt (g)

 
208
 

 
208
Real Estate (h)

 

 
1,137
 
1,137
Cash and Cash Equivalents (i)
188
 
477
 

 
665
Futures (j)
192
 
37
 

 
229
Hedge Funds (k)

 

 
224
 
224
Total investments
$6,389
 
$4,551
 
$1,475
 
$12,415
Funds for retiree health benefits (l)
(184)
 
(131)
 
(43)
 
(358)
Investments (excluding funds for retiree health benefits)
$6,205
 
$4,420
 
$1,432
 
$12,057
Pending activities (m)
 
 
 
 
 
 
(562)
Total fair value of plan net assets
 
 
 
 
 
 
$11,495
(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)
Private Equity consists of global equity funds that are not exchange-traded.
(d)
U.S. Government Issued Debt includes agency and treasury securities.
(e)
Corporate Bonds Debt consists of debt issued by various corporations.
(f)
Structured Assets Debt includes commercial-mortgage-backed securities and collateralized mortgage obligations.
(g)
Other Fixed Income Debt includes municipal bonds, sovereign debt and regional governments.
(h)
Real Estate investments include real estate funds based on appraised values that are broadly diversified by geography and property type.
(i)
Cash and Cash Equivalents include short term investments, money markets, foreign currency and cash collateral.
(j)
Futures consist of exchange-traded financial contracts encompassing U.S. Equity, International Equity and U.S. Government indices.
(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.
The table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2014 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)
Beginning Balance as of January 1, 2014
Assets Still Held
at Reporting Date –
Unrealized
Gains/(Losses)
Assets Sold
During the
Year – Realized
Gains/(Losses)
Purchases
Sales and
Settlements
Transfer
In/(Out) of
Level 3
Ending Balance as of December 31, 2014
Real Estate
$1,062
$86
$20
$(31)

$—

$1,137
Private Equity
67
12

35

114
Hedge Funds
206
11

7

224
Total investments
$1,335
$109
$20
$11

$—

$1,475
Funds for retiree health benefits
(42)
(1)



(43)
Investments (excluding funds for retiree health benefits)
$1,293
$108
$20
$11

$—

$1,432
The Companies also offer a defined contribution savings plan that covers substantially all employees and made contributions to the plan as follows:

117



  
              For the Years Ended December 31,
(Millions of Dollars)
2015
 
2014
 
2013
Con Edison
$34
 
$32
 
$30
CECONY
29
 
27
 
26
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 non-contributory life insurance program for retirees. Certain employees of Con Edison’s competitive 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 2015, 2014 and 2013 were as follows:
  
Con Edison
CECONY
(Millions of Dollars)
2015
2014
2013
2015
2014
2013
Service cost
$20
$19
$23
$15
$15
$18
Interest cost on accumulated other postretirement benefit obligation
51
60
54
43
52
46
Expected return on plan assets
(78)
(77)
(77)
(68)
(68)
(68)
Recognition of net actuarial loss
31
57
65
28
51
57
Recognition of prior service cost
(20)
(19)
(27)
(14)
(15)
(23)
TOTAL PERIODIC POSTRETIREMENT BENEFIT COST
$4
$40
$38
$4
$35
$30
Cost capitalized
(2)
(15)
(15)
(2)
(14)
(12)
Reconciliation to rate level
14
10
58
6
2
50
Cost charged to operating expenses
$16
$35
$81
$8
$23
$68
Funded Status
The funded status of the programs at December 31, 2015, 2014 and 2013 were as follows:

118




  
Con Edison
CECONY
(Millions of Dollars)
2015

2014

2013

2015

2014

2013

CHANGE IN BENEFIT OBLIGATION
 
 
 
 
 
 
Benefit obligation at beginning of year
$1,411
$1,395
$1,454
$1,203
$1,198
$1,238
Service cost
20
19
23
15
15
18
Interest cost on accumulated postretirement benefit obligation
51
60
54
43
52
46
Amendments

(12)




Net actuarial loss/(gain)
(103)
47
(42)
(85)
28
(20)
Benefits paid and administrative expenses
(127)
(134)
(136)
(117)
(125)
(126)
Participant contributions
35
36
38
34
35
38
Medicare prescription subsidy


4


4
BENEFIT OBLIGATION AT END OF YEAR
$1,287
$1,411
$1,395
$1,093
$1,203
$1,198
CHANGE IN PLAN ASSETS
 
 
 
 
 
 
Fair value of plan assets at beginning of year
$1,084
$1,113
$1,047
$950
$977
$922
Actual return on plan assets
(6)
59
153
(4)
54
134
Employer contributions
6
7
9
6
7
9
EGWP payments
28
12
8
26
11
7
Participant contributions
35
36
38
34
35
38
Benefits paid
(153)
(143)
(142)
(142)
(134)
(133)
FAIR VALUE OF PLAN ASSETS AT END OF YEAR
$994
$1,084
$1,113
$870
$950
$977
FUNDED STATUS
$(293)
$(327)
$(282)
$(223)
$(253)
$(221)
Unrecognized net loss
$28
$78
$70
$4
$45
$54
Unrecognized prior service costs
(51)
(71)
(78)
(32)
(46)
(61)
The decrease in the other postretirement benefit plan obligation (due primarily to increased discount rates) was the primary cause of the decreased liability for other postretirement benefits at Con Edison and CECONY of $34 million and $30 million, respectively, compared with December 31, 2014. For Con Edison, this decreased liability corresponds with an increase to regulatory liabilities of $30 million for unrecognized net losses and unrecognized prior service costs associated with the Utilities consistent with the accounting rules for regulated operations, and an immaterial change to OCI (net of taxes) for the unrecognized net losses and a credit to OCI of $1 million (net of taxes) for the unrecognized prior service costs associated with the competitive energy businesses and O&R’s New Jersey subsidiary.
For CECONY, the decrease in liability corresponds with an increase to regulatory liabilities of $27 million for unrecognized net losses and unrecognized prior service costs associated with the company consistent with the accounting rules for regulated operations, and an immaterial change to OCI (net of taxes) for the unrecognized net losses and unrecognized prior service costs associated with the competitive energy businesses.
A portion of the unrecognized net losses and prior service costs for the other postretirement benefits, equal to $12 million and $(20) 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 $10 million and $(14) million, respectively, for CECONY.
Assumptions
The actuarial assumptions were as follows: 

119



 
2015

2014

2013

Weighted-average assumptions used to determine benefit obligations at December 31:
 
 
 
Discount Rate
 
 
 
CECONY
4.05
%
3.75
%
4.50
%
O&R
4.20
%
3.85
%
4.75
%
Weighted-average assumptions used to determine net periodic benefit cost for the years ended December 31:
 
 
 
Discount Rate
 
 
 
CECONY
3.75
%
4.50
%
3.75
%
O&R
3.85
%
4.75
%
4.05
%
Expected Return on Plan Assets
7.75
%
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, 2015 was 5.25 percent, which is assumed to decrease gradually to 4.50 percent by 2018 and remain at that level thereafter. The health care cost trend rate used to determine benefit obligations as of December 31, 2015 was 6.00 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
$(18)
$41
$(37)
$56
Effect on service cost and interest cost components for 2015
(1)
1
(3)
2

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)
2016
2017
2018
2019
2020
2021-2025
Con Edison
$95
$93
$91
$88
$85
$403
CECONY
85
83
81
78
75
348
Expected Contributions
Based on estimates as of December 31, 2015, Con Edison expects to make a contribution of $5 million, nearly all of which is for CECONY, to the other postretirement benefit plans in 2016. 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 2015, 2014 and 2013, and the target allocation for 2016 are as follows:
  
Target Allocation Range
 
Plan Assets at December 31,
Asset Category
2016
 
2015

 
2014

 
2013

Equity Securities
57% - 73%
 
59
%
 
59
%
 
61
%
Debt Securities
26% - 44%
 
41
%
 
41
%
 
39
%
Total
100%
 
100
%
 
100
%
 
100
%

120




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, 2015 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
 
Level 3

 
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
 
43
 
325
Investments (including funds for retiree health benefits)
$162
 
$780
 
$43
 
$985
Pending activities (e)
 
 
 
 
 
 
9
Total fair value of plan net assets
 
 
 
 
 
 
$994
(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)
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 table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2015 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)
Beginning Balance as of January 1, 2015
Assets Still Held
at Reporting Date –
Unrealized
Gains/(Losses)
Assets Sold
During the
Year – Realized
Gains/(Losses)
Purchases
Sales and
Settlements
Transfers
In/(Out) of
Level 3
Ending Balance as of
December 31, 2015
Total investments

$—


$—


$—


$—


$—


$—

Funds for retiree health benefits
43




43
Investments (including funds for retiree health benefits)
$43

$—


$—


$—


$—

$43
The fair values of the plan assets at December 31, 2014 by asset category (see Note P) are as follows:
(Millions of Dollars)
Level 1

 
Level 2
 
Level 3

 
Total
Equity (a)

$—

 
$428
 

$—

 
$428
Other Fixed Income Debt (b)

 
286
 

 
286
Cash and Cash Equivalents (c)

 
11
 

 
11
Total investments

$—

 
$725
 

$—

 
$725
Funds for retiree health benefits (d)
184
 
131
 
43
 
358
Investments (including funds for retiree health benefits)
$184
 
$856
 
$43
 
$1,083
Pending activities (e)
 
 
 
 
 
 
1
Total fair value of plan net assets
 
 
 
 
 
 
$1,084
(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.

121



(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)
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 table below provides a reconciliation of the beginning and ending net balances for assets at December 31, 2014 classified as Level 3 in the fair value hierarchy.
(Millions of Dollars)
Beginning Balance as of January 1, 2014
Assets Still Held
at Reporting Date –
Unrealized
Gains/(Losses)
Assets Sold
During the
Year – Realized
Gains/(Losses)
Purchases
Sales and
Settlements
Transfers
In/(Out) of
Level 3
Ending Balance as of
December 31, 2014
Total investments

$—


$—


$—


$—


$—


$—

Funds for retiree health benefits
42
1



43
Investments (including funds for retiree health benefits)
$42
$1

$—


$—


$—

$43
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, 2015 and 2014 were as follows:

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                  Con Edison
 
                CECONY
(Millions of Dollars)
2015
 
2014
 
2015
 
2014
Accrued Liabilities:
 
 
 
 
 
 
 
Manufactured gas plant sites
$679
 
$684
 
$579
 
$587
Other Superfund Sites
86
 
80
 
86
 
79
Total
$765
 
$764
 
$665
 
$666
Regulatory assets
$904
 
$925
 
$800
 
$820
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. Con Edison and CECONY estimate that in 2016 they will incur costs for remediation of approximately $51 million and $36 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. Under their current rate plans, the Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) certain site investigation and remediation costs.
Environmental remediation costs incurred and insurance recoveries received related to Superfund Sites at December 31, 2015 and 2014 were as follows:
  
                 Con Edison
 
                 CECONY
(Millions of Dollars)
2015

 
2014
 
2015

 
2014
Remediation costs incurred
$37
 
$29
 
$34
 
$20
Insurance recoveries received (a)

 
7
 

 
7
(a) Reduced amount deferred for recovery from customers
In 2015, 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 $2.7 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. 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. Trial courts have begun, and unless otherwise determined by an appellate court may continue, to apply a different standard 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. Under its current rate plans, 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, 2015 and 2014 were as follows:

123



  
                Con Edison
 
               CECONY
(Millions of Dollars)
2015
 
2014
 
2015
 
2014
Accrued liability – asbestos suits
$8
 
$8
 
$7
 
$7
Regulatory assets – asbestos suits
$8
 
$8
 
$7
 
$7
Accrued liability – workers’ compensation
$86
 
$83
 
$81
 
$78
Regulatory assets – workers’ compensation
$11
 
$8
 
$11
 
$8
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 ninety 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, 2015, the company has accrued its estimated liability for the suits of $50 million and an insurance receivable in the same amount.
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 one case, 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 related to the incident. At December 31, 2015, the company had not accrued a liability for 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 $2,856 million and $2,547 million at December 31, 2015 and 2014, respectively.
A summary, by type and term, of Con Edison’s total guarantees at December 31, 2015 is as follows:

124




Guarantee Type
0 – 3 years
 
4 – 10 years

 
> 10 years

 
Total
 
(Millions of Dollars)
NY Transco
$791
 
$567
 

$—

 
$1,358
Energy transactions
792
 
35
 
97
 
924
Renewable electric production projects
471
 
1
 
27
 
499
Other
75
 

 

 
75
Total
$2,129
 
$603
 
$124
 
$2,856
NY Transco – Con Edison has guaranteed payment by CET Electric of the contributions it 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. NY Transco’s transmission projects are being developed initially by CECONY and other New York transmission owners and are expected to be sold to NY Transco. The development of the projects would be subject to authorizations from the NYSPSC, the FERC and other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of CET Electric's contributions, which assumes that all of the NY Transco projects proposed when NY Transco was formed receive all required regulatory approvals and are completed at 175 percent of their estimated costs and that NY Transco does not use any debt financing to construct the projects. Guarantee term shown is assumed as the timing of the contributions is not certain.
Energy Transactions – Con Edison guarantees payments on behalf of its competitive energy businesses in order to facilitate physical and financial transactions in gas, pipeline capacity, oil, electricity, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet.
Renewable Electric Production Projects – Con Edison, Con Edison Development and Con Edison Solutions guarantee payments associated with investments in solar and wind energy facilities by their wholly-owned subsidiaries.
Other – Other guarantees primarily relate to $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with energy service projects and operation of solar energy facilities of Con Edison Solutions and Con Edison Development, respectively. In addition, Con Edison issued a guarantee to the Public Utility Commission of Texas covering obligations of Con Edison Solutions as a retail electric provider. Con Edison’s estimate of the maximum potential obligation for this guarantee is $5 million as of December 31, 2015.
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.
At December 31, 2015, 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

299
November 1996
40
Linden Cogeneration
Cogen Technologies Linden Venture, LP
1,035

609
May 1992
25
Indian Point
Entergy Nuclear Power Marketing, LLC
2,311

500
August 2001
16
Astoria Energy
Astoria Energy, LLC
640

500
May 2006
10
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:

125



(Millions of Dollars)
2016
 
2017
 
2018
 
2019
 
2020
 
All Years
Thereafter
Con Edison
$222
 
$207
 
$181
 
$98
 
$53
 
$762
CECONY
218
 
205
 
181
 
98
 
53
 
762
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 2015, 2014 and 2013 were as follows:
 
               For the Years Ended December 31,
(Millions of Dollars)
2015

 
2014
 
2013
Linden Cogeneration
$323
 
$381
 
$346
Indian Point
226
 
247
 
220
Astoria Energy
178
 
230
 
183
Brooklyn Navy Yard
113
 
133
 
118
Indeck Corinth (a)
25
 
80
 
79
Selkirk (b)

 
144
 
215
Independence (b)

 
97
 
121
Total
$865
 
$1,312
 
$1,282
(a) Contract term ended in 2015.
(b) 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, 2015 and 2014:
  
                 Con Edison
 
                  CECONY
(Millions of Dollars)
2015
 
2014
 
2015
 
2014
UTILITY PLANT
 
 
 
 
 
 
 
Common
$3
 
$3
 
$2
 
$1
The accumulated amortization of the capital leases for Con Edison and CECONY was $3 million and $2 million, respectively at December 31, 2015, and $2 million and $1 million, respectively at December 31, 2014.
The future minimum lease commitments for the above assets are as follows:
(Millions of Dollars)
Con Edison
 
CECONY
2016
$1
 
$1
2017
1
 
1
2018
1
 
1
2019
 
2020
 
All years thereafter
 
Total
3
 
3
Less: amount representing interest
1
 
1
Present value of net minimum lease payment
$2
 
$2

126




Operating leases: The future minimum lease commitments under the Companies’ non-cancelable operating lease agreements are as follows:
(Millions of Dollars)
Con Edison
 
CECONY
2016
$18
 
$12
2017
18
 
12
2018
18
 
12
2019
16
 
10
2020
15
 
9
All years thereafter
123
 
42
Total
$208
 
$97
Lease In/Lease Out Transactions
In each of 1997 and 1999, Con Edison Development entered into transactions in which it leased property and then immediately subleased the properties back to the lessor (termed “Lease In/Lease Out,” or LILO transactions). The transactions respectively involved electric generating and gas distribution facilities in the Netherlands. In accordance with the accounting rules for leases, Con Edison accounted for the two LILO transactions as leveraged leases.
In 2013, the Court of Appeals for the Federal Circuit reversed a lower court decision and disallowed tax losses in connection with the 1997 LILO transaction and Con Edison entered into a closing agreement with the Internal Revenue Service (IRS) regarding the 1997 and 1999 LILO transactions. In addition, in 2013, Con Edison recorded an after-tax charge of $150 million to reflect, as required by the accounting rules for leveraged lease transactions, the recalculation of the accounting effect of the LILO transactions based on the revised after-tax cash flows projected from the inception of the leveraged leases as well as the interest on the potential tax liability resulting from the disallowance of federal and state income tax losses for the LILO transactions. Also, in 2013, the LILO transactions were terminated, as a result of which the company realized a $55 million gain (after-tax). In 2014, adjustments were made to the interest accrued on the liability and the related taxes resulting in a decrease to net income of $1 million. Adjustments made in 2015 were immaterial.
The effect on Con Edison’s consolidated income statement for the twelve months ended as of December 31, 2014 and 2013 was as follows:
  
                    For the Years Ended December 31,
(Millions of Dollars)
2014

2013
Increase/(decrease) to non-utility operating revenues

$—

$(27)
(Increase)/decrease to other interest expense
13
(131)
Income tax benefit/(expense)
(14)
63
Total increase/(decrease) in net income
$(1)
$(95)
Note K – Goodwill
In 2015 and 2014, 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 2015 and 2014, Con Edison also completed impairment tests for the goodwill of $23 million related to two energy services companies acquired by Con Edison Solutions and a gas storage company acquired by Con Edison Development, and determined that the goodwill was not impaired. Estimates of future cash flows, projected growth rates, and discount rates inherent in the cash flow estimates for the energy services companies and gas storage company may vary significantly from actual results, which could result in a future impairment of goodwill.

127



Note L – Income Tax
The components of income tax are as follows:
  
Con Edison
 
CECONY
(Millions of Dollars)
2015
 
2014
 
2013
 
2015
 
2014
 
2013
State
 
 
 
 
 
 
 
 
 
 
 
Current
$38
 
$59
 
$151
 
$48
 
$66
 
$111
Deferred
93
 
61
 
(70)
 
82
 
65
 
(14)
Federal
 
 
 
 
 
 
 
 
 
 
 
Current
(86)
 
(9)
 
285
 
77
 
158
 
187
Deferred
569
 
463
 
115
 
372
 
271
 
241
Amortization of investment tax credits
(9)
 
(6)
 
(5)
 
(5)
 
(5)
 
(5)
Total income tax expense
$605
 
$568
 
$476
 
$574
 
$555
 
$520
The tax effects of temporary differences, which gave rise to deferred tax assets and liabilities, are as follows:
  
                Con Edison
                CECONY
(Millions of Dollars)
2015
2014

2015

2014

Deferred tax liabilities:
 
 
 
 
Property basis differences
$8,614
$7,510
$7,922
$6,938
Regulatory assets:
 
 
 
 
Unrecognized pension and other postretirement costs
1,562
1,968
1,490
1,872
Future income tax
947
910
899
863
Environmental remediation costs
365
376
322
333
Deferred storm costs
75
129
45
91
Other regulatory assets
367
347
308
300
   Equity investments
295
168


Total deferred tax liabilities
$12,225
$11,408
$10,986
$10,397
Deferred tax assets:
 
 
 
 
   Accrued pension and other postretirement costs
$982
$1,306
$857
$1,155
   Regulatory liabilities
836
615
752
574
Superfund and other environmental costs
308
306
268
264
Asset retirement obligations
97
77
94
75
Loss carryforwards
29
21


Tax credits carryforward
258

1

Valuation allowance
(15)
(11)


Other
362
272
292
203
Total deferred tax assets
2,857
2,586
2,264
2,271
Net deferred tax liabilities
$9,368
$8,822
$8,722
$8,126
Unamortized investment tax credits
169
126
33
37
Net deferred tax liabilities and unamortized investment tax credits
$9,537
$8,948
$8,755
$8,163
In November 2015, the Financial Accounting Standards Board (FASB) issued ASU No. 2015-17, “Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes,” which requires that all deferred tax liabilities and assets be classified as noncurrent on the balance sheet. The Companies adopted this new pronouncement for the year ended December 31, 2015 and applied it retrospectively. As a result, Con Edison and CECONY adjusted $128 million and $94 million, respectively, from current deferred tax assets to noncurrent deferred tax income taxes and unamortized investment tax credits on the Companies' consolidated balance sheets at December 31, 2014.
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:

128




  
Con Edison
 
CECONY
(% of Pre-tax income)
2015

 
2014

 
2013

 
2015

 
2014

 
2013

STATUTORY TAX RATE
 
 
 
 
 
 
 
 
 
 
 
Federal
35
%
 
35
%
 
35
%
 
35
%
 
35
%
 
35
%
Changes in computed taxes resulting from:
 
 
 
 
 
 
 
 
 
 
 
State income tax
5

 
5

 
4

 
5

 
5

 
5

Cost of removal
(5
)
 
(5
)
 
(5
)
 
(5
)
 
(5
)
 
(5
)
Manufacturing deduction

 

 
(1
)
 

 

 

Other
(1
)
 
(1
)
 
(2
)
 

 
(1
)
 
(1
)
Effective tax rate
34
%
 
34
%
 
31
%
 
35
%
 
34
%
 
34
%
In 2015, Con Edison had a federal net operating loss, due primarily to accelerated bonus depreciation. The Company expects to carryback its 2015 net operating loss to 2013 and recover $6 million of 2013 income tax. Con Edison has $258 million in general business tax credits, which if unused will begin to expire in 2032. A deferred tax asset for this tax attribute carryforward was recorded, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized. As a result of the extension of bonus depreciation for 2015 and 2016 (see discussion below), Con Edison recorded a full valuation allowance of $4 million in 2015 against its charitable contribution carryforwards of $1 million and $9 million from 2010 and 2011, respectively, that will expire in 2015 and 2016. In addition, an $11 million valuation allowance for New York City income tax purposes 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. In December 2014, President Obama signed into law the Tax Increase Prevention Act of 2014, which 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 million for CECONY) in estimated federal tax payments and received the refund in March 2015.

In December 2015, President Obama signed into law the Protecting Americans from Tax Hikes Act of 2015, which extends bonus depreciation for property acquired and placed in service during 2015 through 2019. The bonus depreciation percentage is 50 percent for property placed in service during 2015, 2016 and 2017 and phases down to 40 percent in 2018, and 30 percent in 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 million in 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:

129



 
Con Edison
CECONY
(Millions of Dollars)
2015

2014

2013

2015

2014

2013

Balance at January 1,
$34
$9
$86
$2

$—

$74
Additions based on tax positions related to the current year


5



Additions based on tax positions of prior years
1
27
253

2

Reductions for tax positions of prior years

(2)
(86)


(74)
Reductions from expiration of statute of limitations
(1)





Settlements


(249)



Balance at December 31,
$34
$34
$9
$2
$2

$—

As of December 31, 2015, Con Edison reasonably expects to resolve approximately $25 million ($16 million, net of federal taxes) of its uncertainties related to certain tax matters within the next twelve months. Favorable resolution would reduce Con Edison’s effective tax rate. The amount related to CECONY is approximately $2 million ($1 million, net of federal taxes), of which the entire amount, 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 2015 and 2014, the Companies recognized an immaterial amount of interest and no penalties for uncertain tax positions in their consolidated income statements. In 2013, Con Edison recognized $121 million of interest expense ($131 million related to the LILO transactions (see “Lease In/Lease Out Transactions” in Note J), less a reduction of $10 million in accrued interest expense primarily associated with repair allowance deductions and reversing other uncertain tax positions in 2013). At December 31, 2015 and 2014, the Companies recognized an immaterial amount of interest and no penalties in their consolidated balance sheets.
At December 31, 2015, the total amount of unrecognized tax benefits that, if recognized, would reduce the Companies’ effective tax rate is $34 million ($22 million, net of federal taxes) with $2 million ($1 million, net of federal taxes) attributable to CECONY.
The federal tax returns for 2012 through 2014 remain open for examinations. State income tax returns remain open for examination in New York for tax years 2006 through 2014 and in New Jersey for tax years 2008 through 2014.
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, 2015 were treasury shares and new shares. The Companies intend to use new shares to fulfill their stock-based compensation obligations for 2016.
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, 2015, 2014 and 2013:

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Con Edison
 
CECONY
(Millions of Dollars)
2015
 
2014
 
2013
 
2015
 
2014
 
2013
Performance-based restricted stock
$27
 
$22
 
$20
 
$23
 
$19
 
$18
Time-based restricted stock
1
 
2
 
2
 
1
 
2
 
2
Non-employee director deferred stock compensation
2
 
2
 
2
 
2
 
2
 
2
Stock purchase plan
4
 
3
 
3
 
3
 
3
 
3
Total
$34
 
$29
 
$27
 
$29
 
$26
 
$25
Income tax benefit
$14
 
$12
 
$11
 
$12
 
$10
 
$10
Stock Options
The Companies last granted stock options in 2006. The stock options generally vested over a three-year period and have 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.
The outstanding options are “equity awards” because shares of Con Edison common stock are delivered upon exercise of the options. As equity awards, the fair value of the options is measured at the grant date.
A summary of changes in the status of stock options as of December 31, 2015 is as follows:
 
Con Edison
 
CECONY
 
Shares
 
Weighted
Average
Exercise
Price
 
Shares

 
Weighted
Average
Exercise
Price
Outstanding at December 31, 2014
229,850
 
$42.99
 
191,350
 
$43.00
Exercised
150,225
 
42.71
 
125,575
 
42.74
Forfeited
500
 
43.50
 

 
Outstanding at December 31, 2015 (a)
79,125
 
$43.50
 
65,775
 
$43.50
(a) The weighted average remaining contractual life is one year for all outstanding options as of December 31, 2015.
The following table summarizes information about stock options for the years ended December 31, 2015 and 2014:
  
                  Con Edison
 
                 CECONY
(Millions of Dollars)
2015
 
2014
 
2015
 
2014
Aggregate intrinsic value (a)
 
 
 
 
 
 
 
Options outstanding
$2
 
$5
 
$1
 
$4
Options exercised
3
 
4
 
3
 
3
Cash received by Con Edison for payment of exercise price
6
 
11
 
5
 
8
(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, 2015, 2014 and 2013 was $1 million, $1 million and $10 million, respectively.
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

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(ii) 50 percent of the units awarded will be multiplied by a factor that may range from 0 to 120 percent for management employees and from 0 to 200 percent, based on 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:
 
2015
 
2014
 
2013
Risk-free interest rate (a)
0.64% - 3.28%
 
0.23% - 3.07%
 
0.13% - 5.17%
Expected term (b)
3 years
 
3 years
 
3 years
Expected share price volatility (c)
15.82%
 
13.14%
 
13.52%
(a)
The risk-free rate is based on the U.S. Treasury zero-coupon yield curve on the date of grant.
(b)
The expected term of the Performance RSUs equals the vesting period. The Companies do not expect significant forfeitures to occur.
(c)
The expected volatility is calculated using daily closing stock prices over a period of three years, which approximates the expected term of the awards.
A summary of changes in the status of the Performance RSUs’ TSR and non-TSR portions during the year ended December 31, 2015 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, 2014
1,100,607
$42.33
$56.61
880,523
$42.58
$56.70
Granted
363,900
57.67
63.22
288,669
57.22
63.12
Vested
(327,536)
49.45
58.84
(266,683)
49.34
58.83
Forfeited
(58,632)
43.84
58.25
(49,252)
43.54
58.14
Non-vested at December 31, 2015
1,078,339
$45.26
$58.08
853,257
$45.37
$58.12
(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, 2015 is $29 million, including $23 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 have accrued a liability based on the market value of a common share on the grant date and are recognizing compensation expense over 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, 2015 is as follows:

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Con Edison
 
CECONY
 
Units
 
Weighted Average Grant Date
Fair Value
 
Units
 
Weighted Average Grant Date
Fair Value
Non-vested at December 31, 2014
65,423
 
$57.65
 
62,173
 
$57.64
Granted
23,000
 
61.00
 
21,800
 
61.00
Vested
(20,773)
 
58.42
 
(19,773)
 
58.42
Forfeited
(2,670)
 
58.35
 
(2,570)
 
58.39
Non-vested at December 31, 2015
64,980
 
$58.56
 
61,630
 
$58.55
The total expense to be recognized by Con Edison in future periods for unvested time-based awards outstanding at December 31, 2015 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, 2015, approximately 30,724 units were issued at a weighted average grant date price of $61.31.
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 2015, 2014 and 2013, 761,784, 708,276 and 864,281 shares were purchased under the Stock Purchase Plan at a weighted average price of $62.75, $56.23 and $57.24 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 and Con Edison’s competitive energy businesses. CECONY’s principal business segments are its regulated electric, gas and steam utility activities.
All revenues of these business segments are from customers located in the United States of America. Also, all assets of the business segments are located in the United States of America. The accounting policies of the segments are the same as those described in Note A.
Common services shared by the business segments are assigned directly or allocated based on various cost factors, depending on the nature of the service provided.
The financial data for the business segments are as follows:

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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
Interest
charges
Income
taxes on
operating
income (a)
Total
assets (b)
Construction
expenditures
CECONY
 
 
 
 
 
 
 
 
Electric
$8,172
$18
$820
$1,798
$447
$447
$30,603
$1,658
Gas
1,527
6
142
356
96
100
6,974
671
Steam
629
86
78
93
41
41
2,653
106
Consolidation adjustments

(110)






Total CECONY
$10,328

$—

$1,040
$2,247
$584
$588
$40,230
$2,435
O&R
 
 
 
 
 
 
 
 
Electric
$663

$—

$50
$103
$23
$31
$2,140
$114
Gas
182

18
18
12
2
579
46
Other (b)








Total O&R
$845

$—

$68
$121
$35
$33
$2,719
$160
Competitive energy businesses
$1,383
$(2)
$22
$58
$11
$22
$1,680
$823
Other (c)
(2)
2

1
23
1
1,013

Total Con Edison
$12,554

$—

$1,130
$2,427
$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
Interest
charges
Income
taxes on
operating
income (a)
Total
assets (b)(d)
Construction
expenditures
CECONY
 
 
 
 
 
 
 
 
Electric
$8,437
$16
$781
$1,712
$412
$425
$30,295
$1,500
Gas
1,721
6
132
314
89
88
6,478
549
Steam
628
84
78
113
36
49
2,670
83
Consolidation adjustments

(106)






Total CECONY
$10,786

$—

$991
$2,139
$537
$562
$39,443
$2,132
O&R
 
 
 
 
 
 
 
 
Electric
$680

$—

$46
$103
$24
$29
$2,023
$105
Gas
212

15
25
10
6
786
37
Other (b)




1

1

Total O&R
$892

$—

$61
$128
$35
$35
$2,810
$142
Competitive energy businesses
$1,244
$(10)
$19
$(60)
$(8)
$(8)
$1,013
$447
Other (c)
(3)
10

2
27

805

Total Con Edison
$12,919

$—

$1,071
$2,209
$591
$589
$44,071
$2,721
As of and for the Year Ended December 31, 2013
(Millions of Dollars)
Operating
revenues
Inter-
segment
revenues
Depreciation
and
amortization
Operating
income
Interest
charges
Income
taxes on
operating
income (a)
Total
assets (b)(d)
Construction
expenditures
CECONY
 
 
 
 
 
 
 
 
Electric
$8,131
$16
$749
$1,595
$402
$380
$27,547
$1,471
Gas
1,616
5
130
362
83
112
5,977
536
Steam
683
82
67
103
36
39
2,571
128
Consolidation adjustments

(103)






Total CECONY
$10,430

$—

$946
$2,060
$521
$531
$36,095
$2,135
O&R
 
 
 
 
 
 
 
 
Electric
$628

$—

$41
$87
$25
$13
$1,882
$98
Gas
205

15
33
11
7
640
37
Other (b)




1

2

Total O&R
$833

$—

$56
$120
$37
$20
$2,524
$135
Competitive energy businesses
$1,096
$5
$23
$63
$135
$(41)
$1,305
$378
Other (c)
(5)
(5)
(1)
1
26
(6)
527

Total Con Edison
$12,354

$—

$1,024
$2,244
$719
$504
$40,451
$2,648

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(a)
For Con Edison, the income tax expense on non-operating income was $40 million, $21 million and $28 million in 2015, 2014 and 2013, respectively. For CECONY, the income tax expense on non-operating income was $14 million, $7 million and $11 million in 2015, 2014 and 2013, respectively.
(b)
Includes amounts related to the RECO securitization.
(c)
Parent company, consolidation adjustments and Con Edison Transmission. Other does not represent a business segment.
(d)
Reflects $237 million and $196 million in 2014 and 2013, respectively, 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
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 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, 2015 and 2014 were:
(Millions of Dollars)
2015
 
2014
 
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
$59
$(41)
$18
(b)
$111
$(67)
$44
(b)
Current - assets held for sale (c)
51
(50)
1
 



 
Noncurrent
57
(54)
3
 
34
(23)
11
 
Noncurrent - assets held for sale (c)
15
(15)

 



 
Total fair value of derivative assets
$182
$(160)
$22
 
$145
$(90)
$55
 
Fair value of derivative liabilities
 
 
 
 
 
 
 
 
Current
$(144)
$78
$(66)
 
$(242)
$139
$(103)
 
Current - liabilities held for sale (c)
(115)
50
(65)
 



 
Noncurrent
(102)
63
(39)
 
(66)
91
25
 
Noncurrent - liabilities held for sale (c)
(28)
15
(13)
 



 
Total fair value of derivative liabilities
$(389)
$206
$(183)
 
$(308)
$230
$(78)
 
Net fair value derivative assets/(liabilities)
$(207)
$46
$(161)
(b)
$(163)
$140
$(23)
(b)
CECONY
 
 
 
 
 
 
 
 
Fair value of derivative assets
 
 
 
 
 
 
 
 
Current
$40
$(32)
$8
(b)
$26
$(15)
$11
(b)
Noncurrent
48
(47)
1
 
22
(20)
2
 
Total fair value of derivative assets
$88
$(79)
$9
 
$48
$(35)
$13
 
Fair value of derivative liabilities


 
 
 
 
 
 
Current
$(121)
$71
$(50)
 
$(96)
$48
$(48)
 
Noncurrent
(92)
56
(36)
 
(42)
32
(10)
 
Total fair value of derivative liabilities
$(213)
$127
$(86)
 
$(138)
$80
$(58)
 
Net fair value derivative assets/(liabilities)
$(125)
$48
$(77)
(b)
$(90)
$45
$(45)
(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, 2015 and 2014, margin deposits for Con Edison ($26 million and $27 million, respectively) and CECONY ($26 million and $25 million, respectively) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is

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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 (see Note U).

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. Con Edison’s competitive 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, 2015 and 2014:
 
 
              Con Edison
 
              CECONY
(Millions of Dollars)
Balance Sheet Location
2015
 
2014

 
2015

 
2014

Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
 
 
 
 
Current
Deferred derivative gains
$1
 
$(10)
 
$2
 
$(7)
Noncurrent
Deferred derivative gains
1
 
1
 

 
1
Total deferred gains/(losses)
$2
 
$(9)
 
$2
 
$(6)
Current
Deferred derivative losses
$(16)
 
$(75)
 
$(11)
 
$(70)
Current
Recoverable energy costs
(136)
 
36
 
(127)
 
26
Noncurrent
Deferred derivative losses
(25)
 
(17)
 
(23)
 
(17)
Total deferred gains/(losses)
$(177)
 
$(56)
 
$(161)
 
$(61)
Net deferred gains/(losses)
$(175)
 
$(65)
 
$(159)
 
$(67)
 
Income Statement Location
 
 
 
 
 
 
 
Pre-tax gain/(loss) recognized in income
 
 
 
 
 
 
 
 
Purchased power expense
$(109)
(a)
$(37)
(b)

$—

 

$—

 
Gas purchased for resale
(106)
 
(115)
 

 

 
Non-utility revenue
30
(a)
29
(b)

 

 
Other operations and maintenance expense
(1)
(c)

 
(1)
(c)

Total pre-tax gain/(loss) recognized in income
$(186)
 
$(123)
 
$(1)
 

$—

 
(a)
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).
(b)
For the year ended December 31, 2014, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($4 million gain) and purchased power expense ($132 million loss).
(c)
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, 2015:
 
Electric Energy (MWh) (a)(b)
Capacity (MW) (a)
Natural Gas (Dt) (a)(b)
Refined Fuels (gallons)
Con Edison (c)
37,036,264
21,174
50,052,794
3,696,000
CECONY
18,742,050
12,000
47,540,000
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.
(c)
Includes 16,381,544 MWh for electric energy, 7,262 MW for capacity and 580,362 Dt for natural gas derivative transactions that are held for sale.
The Companies are exposed to credit risk related to transactions entered into primarily for the various energy supply and hedging activities by the Utilities and the competitive energy businesses. Credit risk relates to the loss

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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, 2015, Con Edison and CECONY had $212 million and $26 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of $146 million with commodity exchange brokers, $50 million with independent system operators, $8 million with investment-grade counterparties and $8 million with non-investment grade/non-rated counterparties. CECONY’s net credit exposure was with commodity exchange brokers.
The collateral requirements associated with, and settlement of, derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statement of cash flows. Most derivative instrument contracts contain provisions that may require a party to provide collateral on its derivative instruments that are in a net liability position. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the party’s credit ratings.
The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at December 31, 2015:
(Millions of Dollars)
Con Edison (a)
CECONY (a)
Aggregate fair value – net liabilities
$106
$81
Collateral posted
18
17
Additional collateral (b) (downgrade one level from current ratings)
9
6
Additional collateral (b)(c) (downgrade to below investment grade from current ratings)
142
104
 
(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 competitive energy businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post additional collateral of $16 million at December 31, 2015. 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, 2015, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of $6 million.

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

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hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows:
Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange.
Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models.
Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value.
Assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2015 and 2014 are summarized below.
 
2015
2014
(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)
$2
$25
$13
$7
$47
$3
$78
$28
$(27)
$82
Commodity held for sale (f)

63
1
(63)
1





Other (a)(b)(d)
185
112


297
163
116


279
Total assets
$187
$200
$14
$(56)
$345
$166
$194
$28
$(27)
$361
Derivative liabilities:
 
 
 
 
 
 
 
 
 
 
Commodity (a)(b)(c)
$16
$153
$1
$(65)
$105
$18
$246
$8
$(194)
$78
Commodity held for sale (f)
1
133
7
(63)
78





Total liabilities
$17
$286
$8
$(128)
$183
$18
$246
$8
$(194)
$78
CECONY
 
 
 
 
 
 
 
 
 
 
Derivative assets:
 
 
 
 
 
 
 
 
 
 
Commodity (a)(b)(c)
$1
$9
$8
$17
$35
$1
$3
$13
$21
$38
Other (a)(b)(d)
171
105


276
155
106


261
Total assets
$172
$114
$8
$17
$311
$156
$109
$13
$21
$299
Derivative liabilities:
 
 
 
 
 
 
 
 
 
 
Commodity (a)(b)(c)
$14
$129

$—

$(57)
$86
$16
$91

$—

$(49)
$58
 
(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, 2015 and 2014.
(b)
Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.
(c)
The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At December 31, 2015 and 2014, 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.

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(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).
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 competitive energy businesses. The risk management group reports to the Companies’ Vice President and Treasurer.
 
Fair Value of Level 3 at December 31, 2015
 
 
 
 
(Millions of Dollars)
Valuation Techniques
Unobservable Inputs
Range
Con Edison Commodity
Electricity
$(5)
Discounted Cash Flow
Forward energy prices (a)
$18.33-$77.50 per MWh
 
 
Discounted Cash Flow
Forward capacity prices (a)
$1.17-$7.50 per kW-month
Natural Gas
1
Discounted Cash Flow
Forward natural gas prices (a)
$(7.60) - $5.55 per Dt
Transmission Congestion Contracts/Financial Transmission Rights
10
Discounted Cash Flow
Discount to adjust auction prices for inter-zonal forward price curves (b)
40.8%-62.1%
 
 
 
Discount to adjust auction prices for historical monthly realized settlements (b)
37.5%-82.2%
 
 
 
Inter-zonal forward price curves adjusted for historical zonal losses (b)
$(6.35)-$5.59 per MWh
Total Con Edison — Commodity
$6
 
 
 
CECONY — Commodity
Transmission Congestion Contracts
$8
Discounted Cash Flow
Discount to adjust auction prices for inter-zonal forward price curves (b)
40.8%-62.1%
 
 
 
Discount to adjust auction prices for historical monthly realized settlements (b)
37.5%-82.2%
 
(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, 2015 and 2014 and classified as Level 3 in the fair value hierarchy:
 
 
                 Con Edison
                 CECONY
(Millions of Dollars)
2015
2014
2015

2014
Beginning balance as of January 1,
$20
$9
$13
$6
Included in earnings
(20)
30
(6)
2
Included in regulatory assets and liabilities
1
7

7
Purchases
11
22
5
16
Settlements
(6)
(48)
(4)
(18)
Ending balance as of December 31,
$6
$20
$8
$13
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 competitive 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 ($14 million loss and $27 million gain) on the consolidated income statement for the years ended December 31, 2015 and 2014, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at December 31, 2015 and 2014 is included in non-utility revenues (immaterial for both years) and purchased

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power costs ($8 million loss and $2 million gain) on the consolidated income statement for the years ended December 31, 2015 and 2014, respectively.
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 has a variable interest in a non-consolidated VIE, Astoria Energy, LLC (Astoria Energy), with which CECONY has entered into a long-term electricity purchase agreement. CECONY is not the primary beneficiary of this VIE since CECONY does not have the power to direct activities that CECONY believes most significantly impact the economic performance of Astoria Energy. In particular, CECONY has not invested in, or guaranteed the indebtedness of, Astoria Energy and CECONY does not operate or maintain Astoria Energy’s generating facilities. CECONY also has long-term electricity purchase agreements with the following two potential VIEs: Cogen Technologies Linden Venture, LP and Brooklyn Navy Yard Cogeneration Partners, LP. In 2015, 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
In 2015, Con Edison Development purchased a 50 percent membership interest in Panoche Holdings, LLC (Panoche Valley). As a result, Con Edison has a variable interest in Panoche Valley, which is a non-consolidated entity. Panoche Valley owns a project company that is developing a 247 MW (AC) solar electric production project in California. Electricity generated by the project is to be sold to the Southern California Edison Company pursuant to a long-term power purchase agreement. Con Edison is not the primary beneficiary since the power to direct the activities that most significantly impact the economics of Panoche Valley is shared equally between Con Edison Development and a third party. At December 31, 2015, Con Edison’s consolidated balance sheet includes $37 million in investments and $77 million representing a note receivable related to Panoche Valley, which assessed in accordance with the accounting rules for variable interest entities, is Con Edison’s current maximum exposure to loss in the entity.
Con Edison has a variable interest in CED California Holdings Financing I, LLC (California Solar), which is no longer a consolidated entity. Con Edison Development sold 50 percent of its membership interest in California Solar which was previously a wholly-owned subsidiary in May 2014. California Solar owns project companies that operate 110 MW (AC) of solar electric production projects in California. Electricity generated by the projects is sold to Pacific Gas and Electric Company pursuant to long-term power purchase agreements. Subsequent to the sale, Con Edison Development’s remaining 50 percent interest in California Solar is accounted for under the equity method.
As a result of the sale, Con Edison Development received net proceeds of $108 million and recognized a pre-tax gain on the sale of $45 million ($26 million, net of tax). The following table summarizes the sale and resultant deconsolidation on the transaction date:

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(Millions of Dollars)
 
Proceeds from sale, net of transaction costs of $1
$108
Non-utility property, less accumulated depreciation
(341)
Other assets, including working capital
(31)
Long-term debt, including current portion
217
Other liabilities
9
Gain on sale of solar electric production projects
(45)
Equity method investment upon deconsolidation
$(83)
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 purchased an 80 percent membership interest in 2014 for $49 million. 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, 2015 and 2014, Con Edison’s consolidated balance sheet includes $58 million in net assets (as detailed in the table below) and the non-controlling interest of the third party of $9 million related to Texas Solar 4. Earnings for the year ended December 31, 2015 and 2014 were immaterial.
(Millions of Dollars)
2015
2014

Restricted cash
$9
$13
Receivable from parent company
32

Non-utility property, less accumulated depreciation of $5 and $1, respectively
107
108
Other assets
11
14
Total assets (a)
$159
$135
Long-term debt due within one year
$2
$66
Other liabilities
37
11
Long-term debt
62

Total liabilities (b)
$101
$77
(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, 2015:
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
$189
Panoche Valley
124
20
2015
California
114
Mesquite Solar 1
83
20
2013
Arizona
110
Copper Mountain Solar 2
75
25
2013
Nevada
85
California Solar
55
25
2012
California
75
Broken Bow II
38
25
2014
Nebraska
55
Pilesgrove
9
n/a (d)
2010
New Jersey
26
Texas Solar 4
32
25
2014
Texas
17
 
(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. 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.
(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 and any related receivables due from the project. For consolidated investments, maximum exposure is equal to the net assets of the investment on the consolidated balance sheet less any applicable noncontrolling interest and receivables from the parent company. Con Edison did not provide any financial or other support during the year that was not previously contractually required.
(d)
Pilesgrove has 3-5 year Solar Renewable Energy Credit hedges in place.

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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 its competitive 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 its competitive 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, 2015, the liabilities for asset retirement obligations of Con Edison and CECONY were $242 million and $234 million, respectively. At December 31, 2014, the liabilities for asset retirement obligations of Con Edison and CECONY were $188 million and $185 million, respectively. The increase in liabilities at December 31, 2015 was due to changes in estimated cash flows of $82 million and $77 million for Con Edison and CECONY, respectively, and accretion expense of $8 million for both Con Edison and CECONY. The increases were offset in part by liabilities settled of $36 million for both Con Edison and CECONY. Con Edison and CECONY also recorded reductions of $23 million and $16 million during the years ended December 31, 2015 and 2014, respectively, to the regulatory liability associated with cost of removal to reflect depreciation and interest expense.
Note S – Related Party Transactions
The Utilities and Con Edison’s competitive 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, 2015, 2014 and 2013 were as follows:

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CECONY
(Millions of Dollars)
2015
2014
2013
Cost of services provided
$99
$90
$84
Cost of services received
60
57
52
In addition, CECONY and O&R have joint gas supply arrangements, in connection with which CECONY sold to O&R $54 million, $80 million and $72 million of natural gas for the years ended December 31, 2015, 2014 and 2013, respectively. These amounts are net of the effect of related hedging transactions.
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, 2015 and 2014.
In January 2016, CECONY entered into an agreement to sell certain electric transmission projects to NY Transco, a company in which CET Electric has a 45.7 percent ownership interest. Also, CECONY, O&R and NY Transco submitted a request to the NYSPSC for authorization in connection with the sale of the projects and the transfer of a substation from CECONY to O&R.
Note T – New Financial Accounting Standards
In May 2014, the FASB and the International Accounting Standards Board (IASB) 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 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. In August 2015, the FASB issued amendments to defer the effective date of ASU No. 2014-09 to reporting periods beginning after December 15, 2017 through ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date”. Early adoption is permitted for reporting periods beginning after December 15, 2016. The Companies are in the process of evaluating the application and impact of the new guidance on the Companies’ financial position, results of operations and liquidity.
In January 2015, the FASB issued amendments on income statement guidance through ASU No. 2015-01, “Income Statement—Extraordinary and Unusual Items (Subtopic 225-20).” The amendments eliminate from GAAP the concept of extraordinary items. The amendments are effective for reporting periods beginning after December 15, 2015. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
In February 2015, the FASB issued amendments on consolidation guidance through ASU No. 2015-02, “Consolidation (Topic 810).” The amendments provide additional guidance for VIE accounting of limited partnerships and similar legal entities, fees paid to decision makers of a VIE, the effect of fee arrangements on primary beneficiary determination, and the effect of related parties on primary beneficiary determination. The amendments are effective prospectively for reporting periods beginning on or after December 15, 2015. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
In April 2015, the FASB issued amendments on internal-use software guidance through ASU No. 2015-05, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Fees Paid in a Cloud Computing Arrangement.” The amendments provide guidance to customers about whether a cloud computing arrangement should be accounted for as a license of internal use software or as a service contract. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2015. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
In May 2015, the FASB issued amendments on disclosure guidance for investments using Net Asset Value per Share through ASU No. 2015-07, “Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent).” The amendments remove the requirement to categorize investments in the fair value hierarchy if Net Asset Value per Share is used as a practical expedient to determine the fair value of the investment. For public entities, the amendments are effective for reporting periods

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beginning on or after December 15, 2015. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.
In July 2015, the FASB issued amendments on the measurement of first-in, first-out and average cost inventory through ASU No.2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory.” The amendments require that inventory within the scope of the guidance be measured at the lower of cost and net realizable value rather than cost and market value. For public entities, the amendments are effective for reporting periods beginning on or after December 15, 2016. 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 September 2015, the FASB issued an amendment to guidance for business combinations through ASU No. 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments.” The amendment requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined as opposed to recognizing retrospectively. The amendment also requires that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. For public entities, the amendment is effective prospectively for reporting periods beginning after December 15, 2015. 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 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 fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Early adoption is permitted. 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.

Note U – Assets Held for Sale
In June 2015, upon evaluating strategic alternatives, Con Edison initiated a plan to sell the retail electric supply business of its competitive energy businesses. The company expects the sale to close within the next twelve months. The company classified as held for sale the related assets and liabilities and ceased recording depreciation expense on these assets. There was no impairment of the assets held for sale, as the estimated fair value less costs to sell exceeded the carrying amount.
In October 2015, upon evaluating strategic alternatives, O&R entered into an agreement to sell Pike to Corning Natural Gas Holding Corporation for $16 million, including estimated working capital adjustments. The closing of the sale, which the company expects to occur within the next twelve months, is subject to certain regulatory approvals by the FERC and Pennsylvania Public Utility Commission. At December 31, 2015, the company classified the related electric and gas assets and liabilities as held for sale and ceased recording depreciation expense on these assets. 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. The impairment is reported in other deductions on Con Edison's consolidated income statement for the year ended December 31, 2015 and reflected in the amount included in assets held for sale on the company's consolidated balance sheet at December 31, 2015.

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At December 31, 2015, the carrying amounts of the assets and liabilities designated as held for sale were as follows:
(Millions of Dollars)
Retail Electric Supply Business
Pike

Total
Cash and temporary cash investments

$—

$4
$4
Accounts receivable, less allowance for uncollectible accounts of $8
64

64
Accrued unbilled revenue
64
1
65
Other assets
2
1
3
Total current assets
130
6
136
Utility plant, less accumulated depreciation of $6

14
14
Non-utility property, less accumulated depreciation of $13
4

4
Regulatory assets

3
3
Total assets held for sale
$134
$23
$157
 




Fair value of derivative liabilities
$65

$—

$65
Accounts payable
5

5
Other
1
2
3
Total current liabilities
71
2
73
Fair value of derivative liabilities
13

13
Long-term debt

3
3
Total liabilities held for sale
$84
$5
$89


145



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)
2015
 
2014
 
2013
Equity in earnings of subsidiaries
$1,195
 
$1,101
 
$1,062
Other income (deductions), net of taxes
27
 
19
 
29
Interest expense
(29)
 
(28)
 
(29)
Net Income
$1,193
 
$1,092
 
$1,062
Comprehensive Income
$1,204
 
$1,072
 
$1,090
Net Income Per Share – Basic
$4.07
 
$3.73
 
$3.62
Net Income Per Share – Diluted
$4.05
 
$3.71
 
$3.61
Dividends Declared Per Share
$2.60
 
$2.52
 
$2.46
Average Number Of Shares Outstanding—Basic (In Millions)
293.0
 
292.9
 
292.9
Average Number Of Shares Outstanding—Diluted (In Millions)
294.4
 
294.0
 
294.4
(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.



146




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)
 
2015
 
2014
 
2013
Net Income
 
$1,193
 
$1,092
 
$1,062
Equity in earnings of subsidiaries
 
(1,195)
 
(1,101)
 
(1,062)
Dividends received from:
 
 
 
 
 
 
CECONY
 
872
 
712
 
728
O&R
 
81
 
40
 
38
Competitive energy businesses
 
8
 
8
 
12
Change in Assets:
 
 
 
 
 
 
Special deposits
 

 
314
 
(264)
Income taxes receivable
 
58
 
(224)
 

Other – net
 
(382)
 
(199)
 
166
Net Cash Flows from Operating Activities
 
635
 
642
 
680
Investing Activities
 
 
 
 
 
 
Contributions to subsidiaries
 
(15)
 
(1)
 

Net Cash Flows Used in Investing Activities
 
(15)
 
(1)
 

Financing Activities
 
 
 
 
 
 
Net proceeds of short-term debt
 
162
 
101
 
58
Retirement of long-term debt
 
(2)
 
(2)
 
(1)
Issuance of common shares for stock plans, net of repurchases
 
1
 
(10)
 
(8)
Common stock dividends
 
(733)
 
(739)
 
(721)
Net Cash Flows Used in Financing Activities
 
(572)
 
(650)
 
(672)
Net Change for the Period
 
48
 
(9)
 
8
Balance at Beginning of Period
 
3
 
12
 
4
Balance at End of Period
 
$51
 
$3
 
$12
(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.



147



Condensed Financial Information of Consolidated Edison, Inc. (a)
Condensed Balance Sheet
(Parent Company Only)
 
 
 
December 31,
(Millions of Dollars)
 
2015
 
2014
Assets
 
 
 
 
Current Assets
 
 
 
 
Cash and temporary cash investments
 
$51
 
$3
Special deposits
 
1
 
1
Accounts receivable – other
 
4
 

Income taxes receivable
 
166
 
224
Accounts receivable from affiliated companies
 
517
 
381
Prepayments
 
34
 
5
Other current assets
 
17
 
4
Total Current Assets
 
790
 
618
Investments in subsidiaries
 
12,737
 
12,277
Goodwill
 
406
 
406
Deferred income tax
 
11
 
18
Other noncurrent assets (b)
 
7
 
8
Total Assets
 
$13,951
 
$13,327
Liabilities and Shareholders’ Equity
 
 
 
 
Current Liabilities
 
 
 
 
Long-term debt due within one year
 
$2
 
$2
Notes payable
 
437
 
274
Accounts payable to affiliated companies
 
146
 
147
Accrued taxes
 

 
13
Other current liabilities
 
10
 
10
Total Current Liabilities
 
595
 
446
Total Liabilities
 
595
 
446
Long-term debt (b)
 
304
 
305
Shareholders’ Equity
 
 
 
 
Common stock, including additional paid-in capital
 
5,062
 
5,023
Retained earnings
 
7,990
 
7,553
Total Shareholders’ Equity
 
13,052
 
12,576
Total Liabilities and Shareholders’ Equity
 
$13,951
 
$13,327
(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.
(b)
Reflects $3 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.” See Note C.


148




Schedule II
Valuation and Qualifying Accounts
For the Years Ended December 31, 2015, 2014 and 2013
 
 
 
 
 
 
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):
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2015
 
$106
 
$77
 

$—

 
$87
 
$96
 
 
 
2014
 
$103
 
$98
 

 
$95
 
$106
 
 
 
2013
 
$105
 
$86
 

 
$88
 
$103
CECONY
Allowance for uncollectible
accounts (a):
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
2015
 
$98
 
$69
 

$—

 
$76
 
$91
 
 
 
2014
 
$95
 
$91
 

 
$88
 
$98
 
 
 
2013
 
$96
 
$82
 

 
$83
 
$95
(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.

149



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.
 


150




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 16, 2016. The proxy statement is to be filed pursuant to Regulation 14A not later than 120 days after December 31, 2015, 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, 2015 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)
843,271
  
 
$43.500
 

2013 LTIP (b)
875,407
  
 

 
4,124,592
Stock Purchase Plan (c)

  
 

 
8,786,339
Total equity compensation plans approved by security holders
1,718,678
  
 

 
12,910,931
Total equity compensation plans not approved by security holders
4,000
(d) 
 

 

Total
1,722,678
  
 

 
12,910,931
(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) outstanding awards made in 2013 (351,269 shares for performance restricted stock units and 21,000 shares for time-based restricted stock units); (B) 267,599 shares for stock unit awards made prior to 2013 that have vested and for which the receipt of shares was deferred; (C) 124,278 shares covered by outstanding directors’ deferred stock unit awards (which vested upon grant) and (D) 79,125 stock options. 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 weighted-average exercise price shown is for stock options; other 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 (733,655 shares for performance restricted stock units and 43,980 shares for time-based restricted stock units); (B) 97,772 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.”
 

151



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 2015 and 2014 are as follows:
 
 
2015
 
2014
Audit fees
$3,423,777
 
$3,329,689
Audit-related fees (a)
8,215
 
281,748
Tax fees (b)
75,088
 

All other fees (c)
102,867
 

Total fees
$3,609,947
 
$3,611,437
(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 2015 are fees related to other accounting and professional services. The major items included in audit-related fees in 2014 are fees for a compliance audit of certain grants received by the Company from the U.S. Department of Energy.
(b)
Relates to fees for tax compliance reporting relating to the Foreign Account Tax Compliance Act.
(c)
Relates to fees 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.
 


152




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 19, 2009. (Designated in Con Edison’s Current Report on Form 8-K, dated February 19, 2009 (File No. 1-14514) as Exhibit 3.1)
 
 
4.1.1
  
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)
 
 
4.1.2
  
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)
 
 
10.1.1.1
  
Credit Agreement, dated as of October 27, 2011, among CECONY, Con Edison, O&R, the lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent. (Designated in Con Edison’s Current Report on Form 8-K dated October 27, 2011 (File No. 1-14514) as Exhibit 10)
 
 
10.1.1.2
  
Extension Agreement, effective August 29, 2013, among CECONY, Con Edison, O&R, the lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent. (Designated in Con Edison’s Current Report on Form 8-K, dated August 29, 2013 (File No. 1-14514) as Exhibit 10)
 
 
10.1.1.3
  
Extension Agreement, effective October 23, 2013, among CECONY, Con Edison, O&R, the lender party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent. (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 10.1.4)
 
 
 
10.1.1.4
 
Amendment No. 1, dated as of January 21, 2016, among CECONY, Con Edison, O&R, the lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent
 
 
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
  
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)
 
 
10.1.4
  
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
  
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)
 
 
 
10.1.6.1
 
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)
 

153




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)
 
 
 
10.1.8
 
Description of Directors’ Compensation, effective as of December 31, 2015
 
 
 
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)
 
 
 
12.1
 
Statement of computation of Con Edison’s ratio of earnings to fixed charges for the years 2011 – 2015
 
 
 
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.
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:
 

154




  
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)
 
 
 
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)
 
 
 
 


155



4.2.16
  
The following forms of CECONY’s Debentures:
  
  
Securities Exchange Act
File No. 1-1217
Debenture
  
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

5.250
%
Series 2005 B
8-K
6/20/2005
4

5.375
%
Series 2005 C
8-K
11/16/2005
4.2

5.85
%
Series 2006 A
8-K
3/9/2006
4

6.20
%
Series 2006 B
8-K
6/15/2006
4

5.50
%
Series 2006 C
8-K
9/25/2006
4

5.30
%
Series 2006 D
8-K
12/1/2006
4.1

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

 
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))
 
 
 
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
 
 
 
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)
 
 
 

156




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 CECONY Severance Pay Plan for Management Employees, 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 10.2.9)
 
 
 
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)
 
 
 
10.2.11.1
 
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
 
 
 
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 2011 – 2015
 
 
 
23.2
 
Consent of PricewaterhouseCoopers LLP
 
 
 
31.2.1
 
Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer
 
 
 
31.2.2
 
Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer
 
 
 
32.2.1
  
Section 1350 Certifications – Chief Executive Officer
 
 
 
32.2.2
  
Section 1350 Certifications – Chief Financial Officer
 
 
 
101.INS
  
XBRL Instance Document
 
 
 
101.SCH
  
XBRL Taxonomy Extension Schema
 
 
 
101.CAL
  
XBRL Taxonomy Extension Calculation Linkbase
 
 
 
101.DEF
  
XBRL Taxonomy Extension Definition Linkbase
 
 
 
101.LAB
  
XBRL Taxonomy Extension Label Linkbase
 
 
 
101.PRE
  
XBRL Taxonomy Extension Presentation Linkbase
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.
 

157



Signatures
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, each Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized, on February 18, 2016.
Consolidated Edison, Inc.
Consolidated Edison Company of New York, Inc.
 
By
/s/ Robert Hoglund
 
 
Robert Hoglund
Senior Vice President and
Chief Financial Officer
 
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant, and in the capacities indicated, on February 18, 2016.
 
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
 
 
 
 


158